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183-066
• • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, June 14, 2017 8:09 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of failed MITIA 1Y-04 (PTD 183-066) 6-14-17 Attachments: 1Y-04 schematic.pdf; 1Y-04 90 day TIO 6-14-17.jpg Chris, KRU WAG injector 1Y-04 (PTD 183-066)failed a MITIA yesterday while prepping the well for upcoming pad testing next month. There were no TIO indications that there was an issue and the MITIA failed when the pressure would not go above 3080psi; a liquid leak rate of'7gpm at 3080psi was established. The well has a known production casing leak at 5764'which was repaired with a seal-tite treatment last year,January 2016. It is suspected that the treatment was holding at the lower operating pressure and let loose when pressuring up the annulus during the test. The well was shut in and freeze protected yesterday and will remain shut in until a path forward can be established with proper paperwork submittal. Please let us know if you disagree with the plan. Attached is the 90 day TIO plot and schematic. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 %MINE© JUN 1 5 2017 Mobile Phone (907) 943-0170 1 • • dwallalioLio Lo 0 cti 4 c> ,i 1. 1 ,1 , t I, .1 , l . !i t r._,t r y.._,q+.writ ..t.. .K._t_*_..1T.._, ''------t C ( ,.. • • - r CD • 0 C O h. N - T - O 7 1 . kl _ - ob r-- • — .I Y -1 11' I I) I 4 ' I '{ I I 4 'I I f I' ' II { 4" f 'I k3 =0 E~- Qa. ) b 8 O O u. 0 ) O Q.) o 5 c-> I ISd 44 • • 0r ( G I- T �' N X RS 4- -a co O Q) E v ° C a C C C T I O fl W CD N Z n m I- o w p N E Ou J Q --I J Q"Cf] W cD O cD c0 c0 O O O cD cD c0 O O -) f- O a� m c) a) a) a) o) o) a) a a ° '� o N Q 0 7 7 = 3 7 = 7 7 o 7 y y U O tF-- C o J Q Q Q Q Q Q Q Q Q Q (n fn 0 Y i. 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Q N ' W N N COCC CO ro C rig ri n d:< t C ' 0C/? o_ kb • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg - DATE: Monday,May 09,2016 P.I.Supervisor kele. Al,e SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I Y-04 FROM: Johnnie Hill KUPARUK RIV UNIT IY-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv � NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-04 API Well Number 50-029-20948-00-00 Inspector Name: Johnnie Hill Permit Number: 183-066-0 Inspection Date: 5/7/2016 Insp Num: mitJWH160508165913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y 04 Type Inj W TVD 5914 - Tubing 2364 2375 - 2330- 2335 - PTD i 1830660 Type Test SPT Test psi 3000 IA 1405 3320 - 3275 3260 Interval(OTHER P/F P ✓ OA 425 425 425 425 Notes: MITIA post Seal-tite repair per Sundry#315-704....Re-test following inconclusive test results om 4-30-16 scANNE® SEP 2 7 2015 Monday,May 09,2016 Page 1 of 1 S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission _ DATE: Wednesday,May 04,2016 TO: Jim Regg 1<a_e651 13la, P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-04 FROM: Chuck Scheve KUPARUK RIV UNIT 1Y-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .JL. . NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-04 API Well Number 50-029-20948-00-00 Inspector Name: Chuck Scheve Permit Number: 183-066-0 Inspection Date: 4/30/2016 Insp Num: mitCS160502071559 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-04 Type Inj W TVD 5914 - Tubing 2298 - 2296 - 2296 - 2296 • PTD 1830660 " ,Type Test.SPT Test psi 1500 - IA 1260 3270 - 3150 - 3130 - Interval OTHER P/Fi I ' OA 430 430 430 430 Notes: Post seal tite repair. During initial test the pressure broke back at 3200 psi and IA was taking fluid. The pump was stopped and the pressure declined rapidly to 2500 psi. Decision was made to attempt to establish a leak rate. While trying to establish a leak rate the pressure gradually incresed and the test was completed with the results listed. 5 bbls were pumped during test and 2 bbls bled back to return to starting pressure. Requested retest in a week or so. SCANNED SEP 2 7 2016 Wednesday,May 04,2016 Page 1 of 1 • • 2C2C0-1� WELL LOG TRANSMITTAL#902843197 DATA LOGGED 2/5/2016 K BENDER To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 20 2.[i;',) RE: Leak Detect Log with ACX: 1Y-04 AOGCC Run Date: 10/22/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-04 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-20948-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-20948-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. sCANNE a ` '"' Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: itDvaL/4420,..,,4eittieve, STATE OF ALASKA KRU 1Y-04 ALtit OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdow n g--' Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved R-ogram r-J Plug for Redrill r Perforate New Pool r Repair Well 17 Re-enter Susp Well r Other:PC Repair(Seal-lite) f✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-066 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20948-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025641 KRU 1 Y-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7420 feet Plugs(measured) None true vertical 6536 feet Junk(measured) 7220 Effective Depth measured 7221 feet Packer(measured) 6658, 6894,7019 true vertical 6373 feet (true vertical) 5914,6107,6209 Casing Length Size MD TVD Burst Collapse CONDUCTOR 41 16 78 78 SURFACE 2218 10 3/4 2254 2254 PRODUCTION 7362 7 7395 6515 CRNNE =err' 4 %; RECEIVED Perforation depth: Measured depth: 6797-6857;6908-6939; 7122-7142; 7124-7140; 7158-7178 JAN 12 2016 True Vertical Depth: 6028.2-6077;6118.5-6143.7; 6292.9-6309.2;6294.5-6307.5; 6322.2-6338.6 p�'��+� AOGCC Tubing(size,grade,MD,and TVD) 3.5",J-55,7027' MD, 6216'TVD; 2.875", J-55,7045' MD, 6231'TVD Packers&SSSV(type,MD,and TVD) PACKER-CAMCO HRP-1-SP PACKER @ 6658 MD and 5914 TVD PACKER-CAMCO HRP-1-SP PACKER @ 6894 MD and 6107 TVD PACKER-BAKER FB-1 PACKER @ 7019 MD and 6209 TVD SAFETY VLV-CAMCO TRDP-IA-ENC SAFETY VALVE @ 1821 MD and 1821 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service P Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and!Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG �. GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-704 Contact Rachel Kautz Email Rachel.Kautz(cr�conocophillips.com Printed Name Rachel Kautz Title Well Integrity Engineer Signature Phone 263-4409 Date 1/9/2016 Vri— III3/f( v 40t Il?g Form 10-404 Revised 5/2015 , RBDM� my 1,2 2016 Submit Original Only • • ConocoPhillips ' RECEIVED Alaska JAN 12 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 9 January 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Ms. Foerster, Enclosed please find the 10-404 for ConocoPhillips Alaska, Inc.'s well 1Y-04 (PTD 183- 066) for repair of the production casing using a Seal-Tite sealant pill. Please call me at 263-4409 if you have any questions. Regards, Rachel Kautz Well Integrity Engineer • 1Y-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/21/15 Ran and set 2.78"WRP. Performed MIT-T to 2500 psi to confirm plug holding (PASSED). 12/22/15 Set 2.79"catcher sub @ 6684' RKB. Pulled 1.5"dummy gas lift valve from Station#9 @ 6593' RKB. Completely circulate 9.6 brine from tubing to IA. Insert Seal-Tite pill (6 bbls) into IA. Pump 146 bbls of diesel into IA behind Seal-Tite pill, taking returns from tubing, to spot Seal-Tite pill at 01/06/16 casing leak site @ 5765'. Slickline set dummy gas lift valve in Station#9 @ 6593' RKB. Passed subsequent MIT-T to 2100 psi confirming dummy gas lift valve set. Slickline pulled the catcher and WRP @ 6684' RKB. Pressured IA to 2000 psi to squeeze sealant as per Seal-Tite procedure. Left 2000 psi on IA overnight to allow sealant to cure. Slowly increased IA pressure in increments to cure sealant. Performed MIT-IA to 3000 psi (PASSED). 01/07/16 Initial T/I/O/OO = 8/3000/400/1. 15 min T/I/O/OO= 8/2995/400/1. 30 min T/I/O/OO = 8/2995/400/1. Bled IA back to 2000 psi and let sealant further cure for 24 hours. 01/08/16 Initial T/I/O = SI/2050/400. Bled IA to 1500 psi. Final T/I/O = SI/1500/400. P OF rFp �w�� %mss, THE STATE Alaska Oil and Gas o f ® Conservation Commission AsKAL 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ; �'' Main: 907.279.1433 OF ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Rachel Kautz � �� 11(, �� Well Integrity Engineer ConocoPhillips Alaska, Inc. ^ O 66 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Y-04 Sundry Number: 315-704 Dear Mr. Kautz: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 2 day of November, 2015 Encl. Y./ RBDMS- DEC 0 12015 �(� ✓ ` °,st" cams • , STATE OF ALASKA ?t ':- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,3 <i a 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. PC Repair(Seal Tite)D. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inca Exploratory ❑ Development ❑ 183-066 3.Address: Stratigraphic ❑ Service ❑, 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20948-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Q KRU 1Y-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025641 • Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7420 • 6536 • 7221 -. 6373 . 2500 None 7220 Casing Length Size MD TVD Burst Collapse Conductor 41 16 78 78 Surface 2218 10 3/4 2254 2254 Production 7362 7 7395 6515 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6797-6857;6908-6939;7122- 6028.2-6077;6118.5-6143.7; 3.5" J-55 7027 7142;7124-7140;7158-7178. 6292.9-6309.2;6294.5-6307.5, 2.875" J-55 7045 6322.2-6338.6 Packers and SSSV Type: PACKERS-CAMCO HRP-1-SP,BAKER FB-1 Packers and SSSV MD(ft)and TVD(ft): PACKERS-6658'MD (5914'TVD),6894'MD SAFETY VLV-CAMCO TRDP-1A-ENC (6107'TVD),7019'MD(6209'TVD) SAFETY VLV-1821'MD(1821'TVD) 12.Attachments: Proposal Summary D Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/1/2015 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Rachel Kautz Email racheikautz@cop.com Printed Name Title Rachel Kautz Well Integrity Engineer Signature Phone 263-4409 Date 11/11/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315-104-{ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: At 1i11.4.n,s.50 At ti, I/4 „112-1_ '4ti,b;4-z....-.L 'k Post Initial Injection MIT Req'd? Yes ❑ No Si Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: `O— '6 APPROVED BY Approved by: SSIONT E COMMISSION Date: // /5- 4.7ALERE& ll1/2015 RrtGINA d for 12 R10111II t tgoi royal. ttac menu in Duplicate • • ., >: ik 1 { ` ConocoPhillips ' " 0 Alaska, Inc. P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 11 November 2015 Ms. Cathy Foerster Alaska Oil&Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Dear Ms. Foerster, Enclosed please find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc.'s well 1Y-04 (PTD 183-066). The request is for approval to repair the production casing using a Seal-Tite sealant pill.'Please call MJ Loveland at 659-7043 or me at 263-4409 if you have any questions. Regards, Rachel Kautz Well Integrity Engineer • • ConocoPhillips Alaska, Inc. Kuparuk Well 1Y-04 (PTD 183-066) SUNDRY NOTICE 10-403 CASING REPAIR 11/11/2015 This Sundry is a request for approval to repair ConocoPhillips Alaska(CPA) Kuparuk Well 1 Y- 04 (PTD 183-066). On July 3, 2009,the AOGCC was notified that the well had failed a diagnostic MITIA. On September 23, 2014, approval was granted from AOGCC to repair the identified production casing leak with Seal-Tite. In October 2014,the approved Seal-Tite operation took place. Testing done after the job revealed a subsequent smaller leak exists in the production casing. CPA intends to repair 1 Y-04 using the following procedure to return the well to "Normal" status capable of injecting miscible injectant (MI). REPAIR PLAN 6684( 1`14� 1. Set plug downhole. 2. Perform MITT to confirm plug is holding. 1 3. Pull gaslift dummy from gas lift mandrel.(+; ) Co`Sq 1k b 4. Circulate tubing and IA using brine with density greater than Seal-Tite sealant pill. 5. Displace Seal-Tite sealant pill down IA to immediately above the leaking interval. 6. Stop circulation, set dummy valve in the open gas lift mandrel it was pulled from and squeeze sealant pill as per Seal-Tite procedure. 7. Perform MITIA in excess of AOGCC minimum pressure. 8. Submit 10-404 to AOGCC post-repair. 9. Place well on injection and perform State witnessed MITIA. 10. If MITIA passes,return to well to "Normal" status allowing MI injection. 11. Return well to standard 4 year State witnessed MITIA schedule . KUP INJ • 1Y-04 ConocoPhillips Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) CmoraMallipr 500292094800 KUPARUK RIVER UNIT INJ 46.58 4,500.00 7,420.0 ... _ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 1Y-04,5/1320159:5743 AM SSSV:TRDP Last WO. 3/14/1987 41.011 5/10/1983 Vertical schematc(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date ---- ' -- �f----Last Tag:SLM 7,183.0 11/26/2014 Rev Reason:SET PATCH hipshkf 5/13/2015 �- 4 •!IPA E °�. Casing Strings HANGER 34 0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread f CONDUCTOR 16 15.060 37.0 78.0 78.0 62.80 H-40 WELDED a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ■ SURFACE 103/4_ 9.950 36.3 2,254.0 2,253.9 45.50 K-55 BUTT , ,.. . ,, , . , . ....,, TI : . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread PRODUCTION 7 6.276 33.0 7,394.8 6,515.3 26.00 J-55 BUTT CONDUCTOR 37.0-78.0 . Tubing Strings Tubing Description String Ma...ID(in) Top(Pith) Set Depth(ft.. (ND)I. Grade Top C nnection 111 TUBING WO 3 1/2 2.992 34.0 7,046.81 Set Depth 6.231.6..Wt(Ib/ft)1 920 J-55 BTC AB-MOD al 3.5"x2.875"" SAFETY VLV;1,820.8 ry=eiyrg Completion Details - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.0 34.0 0.10 HANGER MCEVOY RETROFIT TUBING HANGER 3.500 1,820.8 1,820.7 0.63 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.813 SURFACE;36.3.2,2540-4 6,632.9 5,893.5 34.64 SBR CAMCO OEJ SBR 2.875 GAS LIFT;2,019.a 6,657.5 5,913.8 34.60 PACKER CAMCO HRP-1-SP PACKER 2.867 6,779.8 6,014.2 35.28 BLAST RINGS RICKERT BLAST RINGS(3) 2.867 GAS LIFT;3,645.0 i 6,894.0 6,107.1 35.61 PACKER CAMCO HRP-1-SP PACKER 2.859 GAS LIFT;4,119.6 6,908.3 6,118.8 35.60 BLAST RINGS RICKERT BLAST RINGS(2) 2.867 GAS LIFT;4,592.0 ! 7,008.8 6,200.6 35.34 NIPPLE AVA BPL NIPPLE 2.750 ' 7,017.7 6,207.9 35.35 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;5,065.9 7,019.2 6,209.1 35.36 PACKER BAKER FB-1 PACKER 3.000 ' to--r 7,027.4 6,215.8' 35.37 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS LIFT;5,540.4 • W a' /_'1�1 7,035.7 6,222.6 35.38 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5,985.3 JJ 7,046.0 6,231.0 35.39 SOS CAMCO SHEAR OUT SUB,ELME)TTL @ 7046'during 3.000 all IPROF on 7/13/2008 GAS LIFT,6,398.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IIITop(ND) Top Incl GAS LIFT;6.592.8 1111 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) �� "7 6,766.0 6,002.9 35.15 PACKER 2..72 PARAGON II UPPER PACKER(OAL+3.94") 5/11/2015 1.630 SBR;6,632.9 6,769.9 6,006.1 35.19 PATCH 16'SPACER PIPE 5/11/2015 1.610 PACKER;6,657.5 6,786.0 6,019.2 35.34 PACKER 2..72 PARAGON II LOWER PACKER(OAL+3.94") 5/11/2015 1.630 6,965.0 6,164.9 35.43 PATCH Baker Patch 6960'to 7036'RKB set 8/17/2006. '8/17/2006 1.595 INJECTION;6,699.0 bottom spacer assy#1=31.11'OAL,spacer assy 42=22.40'OAL,upper packer&spacer assy 43=22.49'OAL[combined 76'OALI PACKER;6,766.0 ; .tet., 7,220.0 6,372.9 35.29 FISH Valve Assy&Nozzle 2'Double Check Valve Assy.& 4/11/1993 N. Nozzle from Coil-Downhole INJECTION;6,770 9 PATCH;6,769.9 Perforations&Slots Shot PACKER:6,786.0 -A- Dens Top(TVD) Btm(TVD) (shots/f APERF;6,797.0-6.857 0--.J I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,797.0 6,857.0 6,028.2 6,077.0 C-4,C-3,1Y- 5/23/1983 12.0 APERF 5.5"SOS high density 04 I. 6,908.0 6,939.0 6,118.5 6,143.7 C-1,UNIT B, 5/23/1983 12.0 APERF 5.5"SOS high density INJECTION;6,877.0 1Y-04 7,122.0 7,142.0 6,292.9 6,309.2 A-4,1Y-04 5/23/1983 12.0 RPERF 5.5"SOS high density PACKER;6,8940- - 7,124.0 7,140.0 6,294.5 6,307.5 A-4,1Y-04 4/4/1993 4.0 (PERF 2 1/8"Enerjet;0 deg.Ph APERF;6.9000-6,939.0-- 7,158.0 7,178.0 6,322.2 6,338.6 A-3,1Y-04 5/23/1983 12.0 APERF 5.5"SOS high density IMandrel Inserts st ati on Top(ND) Valve Latch Port Size TRO Run II N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com INJECTION;6,971.7 ( 2,519.4 2,519.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 2 3,645.0 3,605.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1993 PATCH,6,965.0 NIPPLE,7,008e 3 4,119.6 4,009.5 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 3/2/1988 -I. 4 4,592.0 4,355.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 SEAL Asst,7.017.7 5 5,065.9 4,686.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 PACKER,7,0192 6 5,540.4 5,028.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 ■''' 7 5,985.3 5,370.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1993 8 6,398.0 5,700.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 9 6,592.8 5,860.5 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 10/11/2014 NIPPLE;7,035.7 1 6,699.0 5,947.9 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 6/17/2003 Close 11 0 d 1 6,770.9 6,006.9 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 11/2/2008 SOS;7,046.0 V: 1 1 6,876.9 6,093.3 OTIS LBX 1 1/2'INJ DMY RM 0.000 0.0 4/26/2009 2 !PERF;7.124.0-7,140.0 7 1 6,971.7 6,170.4 CAMCO 3.5x 11/2 INJ DMY BK 0.000 0.0 7/10/1993 Close RPERF;7,122.0-7,142.0, - - 3 1.5 d Notes:General&Safety End Date Annotation APERF;7,158.0-7,178.0---. 6/3/2006 NOTE:LEAKS FOUND IN TUBING @ 7001'&6982 10/30/2008 NOTE:Bottom 6"of HFCV left in CSM @ 6771';severe erosion FISH;7,220.06 8/25/2009 NOTE:TECWEL LDL FOUND SUSPECTED CSG LEAK TO FORMATION @ 5760-5764 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;33.0-7,394.8-- • • Schwartz, Guy l (DOA) From: Kautz, Rachel <Rachel.Kautz@conocophillips.com> Sent: Wednesday, November 18, 2015 2:26 PM To: Schwartz, Guy L(DOA) Subject: RE: KRU 1Y-04 sealtite repair(PTD 183-066) Guy, Based on the results of an acoustic log,we estimate the casing leak is at 5765'. The current plan is to set a plug at 6,684' and pull the dummy GLV at 6593'. Regards, Rachel Kautz Well Integrity Engineer ConocoPhillips Alaska Work:907-263-4409 Cell:816-868-2420 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@)alaska.gov] Sent: Tuesday, November 17, 2015 3:47 PM To: Kautz, Rachel Subject: [EXTERNAL]KRU 1Y-04 sealtite repair (PTD 183-066) Rachel, I am looking at your sundry to repair 1Y-04. Where is the PC leak and how did you determine where is was located.?? Please indicate where you are setting the test plug in the tubing and which GLV you are pulling in order to circulate the treatment. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 STATE OF ALASKA • • AL A OIL AND GAS CONSERVATION COM. 3ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations AbandonPlugPerforations r r Fracture Stimulate r Pull Tubing n Operations Shutdow n Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Install Tubing Patch Fi 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 183-066 3 Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20948-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 025641 KRU 1Y-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7420 feet Plugs(measured) none true vertical 6536 feet Junk(measured) 7220 Effective Depth measured 7296 feet Packer(measured) 6658, 6766,6786,6894, 7019 true vertical 6434 feet (true vertical) 5914, 6003,6019,6107, 6209 Casing Length Size MD TVD Burst Collapse CONDUCTOR 41 16 78 78 SURFACE 2218 10.75 2254 2254 PRODUCTION 7362 7 7395 6515 RECEIVED Perforation depth: Measured depth: 6797-6857,6908-6939, 7122-7142, 7158-7178 MAY 20 2015 True Vertical Depth: 6028-6077,6119-6144,6293-6309,6322-6339 AOGCC Tubing(size,grade,MD,and TVD) 3 5 x 2.875,J-55, 7047 MD, 6232 TVD Packers&SSSV(type,MD,and TVD) PACKER-CAMCO HRP-1-SP PACKER @ 6658 MD and 5914 TVD PACKER-2..72 PARAGON II UPPER PACKER(OAL+3.94")@ 6766 MD and 6003 TVD PACKER-2..72 PARAGON II LOWER PACKER(OAL+3 94")@ 6786 MD and 6019 TVD PACKER-CAMCO HRP-1-SP PACKER @ 6894 MD and 6107 TVD PACKER-BAKER FB-1 PACKER @ 7019 MD and 6209 TVD SAFETY VLV-CAMCO TRDP-1A-ENC SAFETY VALVE @ 1821 MD and 1821 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14 Attachments(required per 20 AAC 25.070,25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations Exploratory r Development r Service rr Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or N/A if C.O Exempt 315-029 Contact John Peirce Cad 265-6471 Email John.W.Peirce(a�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature / ! Phone:265-6471 Date /1. 1 I 1 S Form 10-404 Revised 5/2015 V77- VW 15 Submit Original Only 7AST— RBDMS MAY 2 9 2015 1Y-04 WELL WORK SUMMARY DATE SUMMARY 5/10/2015 RAN 2.75"CENT, 3.5" BLB & 2.75" GAUGE RING. BRUSHED DOWN TO 6900' SLM. LRS ASSISTED W/B&F. SET 2.72"OLGNOOK LOWER PACKER @ 6786' RKB. ATTEMPTED TO SET UPPER 2.72" OGLOONIK PARAGON II UPPER PACKER W/ PATCH. S/D @ 6730' SLM, TOOLS WENT PAST THE LOWER PACKER SETTING DEPTH. RECOVERED LOWER PACKER STUNG INTO PATCH ANCHOR LATCH. IN PROGRESS. 5/11/2015 SET 2.72" OLGOONIK PARAGON II LOWER PACKER @ 6786' RKB. SET 2.72"OLGOONIK PARAGON II UPPER PACKER W/SPACER PIPE &ANCHOR LATCH @ 6766' RKB. RAN TEST TOOL TO 6766' RKB.LRS PERFORMED MIT-T.PASSED. • f KUP INJ 1Y-04 CO'tOCOPhiItips o Well Attributes Max Angle&MD TD ' Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c"".,St airy, 500292094800 KUPARUK RIVER UNIT INJ 46.58 4,500.00 7,420.0 ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1Y-04,5/1320159:57:43 AM SSSV:TRDP Last WO. 3/14/1987 41.01 5/10/1983 • Venice/aGromaac(actuaq Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - ------ ----- ----Last Tag:SLM 7,183.0 11/26/2014 Rev Reason: SET PATCH hipshkf 5/132015 IA :f �rf � t . tasing Strings HANGER;34.0 Casing Description 01))int ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len N..Grade Top Thread 116 CONDUCTOR 15.060 37.0 78.0 78.0 62.80 H-40 WELDED 1{ 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I. Len ..Grade Top Thread II SURFACE 103/4 9.950 36.3 2,254.0 2,253.9 45.50 K-55 BUTT r,.r,o.e„a,,,m,,,,.,,.,,,,,,,,,,,"„m,,.,,"„ter •. ism Caning Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) 'Set Depth(ND)... WllLen(I...Grade Top Thread _ PRODUCTION 7 6.276 33.0 7,394.8 6,515.3 26.00 J-55 BUTT ''I CONDUCTOR;370-78.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth)ND)(...Wt)Ib/ft) Grade Top Connection I TUBING WO 31/2 2.992 34.0 7,046.8 6231.6 9.20 J-55 BTC AB-MOD 3.5"x2.875" SAFETY VLV;1.820S Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inci C) Item Des Com • (in) 1 34.0 34.0 0.10 HANGER MCEVOY RETROFIT TUBING HANGER 3.500 1,820.8 1,820.7 0.63 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.813 SURFACE;36.3-2,254.0 6,632.9 5,893.5 34.64 SBR CAMCO OEJ SBR 2.875 GAS LIFT;2,519.46,657.5 5,913.8 34.60 PACKER CAMCO HRP-1-SP PACKER 2.867 GAS LIFT;3,645.0 M 6,779.8 6,014.2 35.28 BLAST RINGS RICKERT BLAST RINGS(3) 2.867 6,894.0 6,107.1 35.61 PACKER CAMCO HRP-1-SP PACKER - 2.859 GAS LIFT;4,119.6 6,908.3 6,118.8 35.60 BLAST RINGS RICKERT BLAST RINGS(2) 2.867 GAS LIFT;4,592.0 7,008.8 6,200.6 35.34 NIPPLE AVA BPL NIPPLE 2.750 7,017.7 6207.9 35.35 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;5.065.9 7,019.2 6,209.1 35.36 PACKER BAKER FB-1 PACKER 3.000 7,027.4 6,215.8- 35.37 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS LIFT;5.540.4 7,035.7 6,222.6 35.38 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5,985.3 7,046.0 6,231.0 35.39 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 7046'during 3.000 (PROF on 7/13/2008 GAS LIFT;6.398.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT,65928 Top(ftKB) (ftKB) r) Des Com Run Date ID(in) 6,766.0 6,002.9 35.15 PACKER 2..72 PARAGON II UPPER PACKER(OAL+3.94") 5/11/2015 1.630 SBR;6,632.9 .: 6,769.9 6,006.1 35.19 PATCH 16'SPACER PIPE 5/11/2015 1.610 PACKER;6,657.5 6,786.0 6,019.2 35.34 PACKER 2..72 PARAGON II LOWER PACKER(OAL+3.94") 5/11/2015 1.630 II 6,965.0 6,164.9 35.43 PATCH Baker Patch 6960'to 7036'RKB set 8/17/2006. 8/172006 1.595 INJECTION;6.699.0 bottom spacer assy#1=31.11'OAL,spacer assy #2=22.40'OAL,upper packer&spacer assy #3=22.49'OAL[combined 76'OAL] PACKER;6.766.0 p: t 7,220.0 6,372.9 35.29 FISH Valve Assy 8 Nozzle 2'Double Check Valve Assy.8 4/11/1993 INJECTION;6,770.9 Nozzle from Coil-Downhole PATCH;8,769.9 Perforations&Slots PACKER;6,7860 Shot _�_ Dens Top(TVD) Btm(TVD) (shots# APERF;6,797.08,857.0- I Top(ftKB) Blot(ftKB) (ftKB) (ftKB) Zone Data t) Type Com 6,797.0 6,857.0 6,028.2 6,077.0 C-4,C-3,1Y- 523/1983 12.0 APERF 5.5"SOS high density ■ 04 wEcnoN;6,877.0 6,908.0 6,939.0 6,118.5 6,143.7 C-1,UNIT B, 523/1983 ' 12.0 APERF 5.5"SOS high density I1Y-04 .- - 7,122.0 7,142.0 6,292.9 6,309.2 A-4,1Y-04 5/23/1983 12.0 RPERF 5.5"SOS high density PACKER;6,894.0 •117,124.0 7,140.0 6,294.5 6,307.5 A-4,1Y-04 4/4/1993 4.0 IPERF 2 1/8"Ener{et;0 deg.Ph APERF;6.908.0-6.939.0 7,158.0 7,178.0 6,322.2 6,338.6 A-3,1Y-04 5/23/1983 ' 12.0 APERF 5.5"SOS high density Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn INJECTION;6.971.7 ( 2,519.4 2,519.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 2 3,645.0 3,605.2 CAMCO KBUG 1"GAS LIFT DMY BK 0.000 0.0 10/23/1993- PATCH;6.965.0 NIPPLE;7.008.8 3 4,119.6 4,009.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 32/1988 4 4,592.0 4,355.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0:4/2/1993 5 5,065.9 4,686.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 SEAL ASSY;7,017.7 6 5,540.4 5,028.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 PACKER;7,019.2 7' 5,985.3 5,370.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1993 - 8 6,398.0 5,700.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 9 6,592.8 5,860.5 OTIS LBX 1 12 GAS LIFT DMY RM ' 0.000 0.0 10/11/2014 NIPPLE;7,035.7 i r 1 6,699.0 5,947.9 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 6/17/2003 Close • 0 d 1 6,770.9 6,006.9 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 112/2008 SOS;7,046.0 F 1 • 1 6,876.9 6,093.3 OTIS LBX 112 INJ DMY RM 0.000 0.0 426/2009 .- 2 IPERF;7,124.0a.140.0 1 6,971.7 6,170.4 CAMCO 3.5 x 1 1/2 INJ DMY BK 0.000 0.0 7/10/1993 Close RPERF;7.122.0.7.14201 --. 3 1.5 d - - Notes:General&Safety End Date Annotation APERF;7,158.0-7,178.0--. 6/3/2006 NOTE:LEAKS FOUND IN TUBING @ 7001'8 6982' 10/30/2008 NOTE:Bottom 6"of HFCV left in CSM @ 6771';severe erosion FISH;7,220.0 IP 825/2009 NOTE:TECWEL LDL FOUND SUSPECTED CSG LEAK TO FORMATION @ 5760-5764 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;33.0-7,394.8-4 • • T ic:OF ����y/j..s, THE STATE Alaska Oil and Gas ��� °fALA Conservation Commission '�� - ==�- S���1 1 g ___. __ 333 West Seventh Avenue OFA,, 5ti D J GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main' 907 279.1433 LA ax. 907.276 7542 www.aogcc.alaska.gov �p �:.- (b 6 2.0a.5 SCIOMJohn Pierce Sr. Wells Engineer „ 0 676 ConocoPhillips Alaska, Inc. I g P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Y-04 Sundry Number: 315-029 Dear Mr. Pierce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ia-40-- -b Cathy P. oerster Chair DATED this day of January, 2015 Encl. STATE OF ALASKA AL_,:A OIL AND GAS CONSERVATION COMMI, JN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Plug for Redrill r Perforate New Pool r Repair w ell IIV Change Approved Program I-- Suspend r Plug Perforations r Perforate r Pull Tubing r Time tension r Operational Shutdown Re-enter Susp.Well p r r Stimulate r Alter casing r Other:lnstall atch 7 .17• 2 Operator Name 4 Current Well Class 5 Permit to rill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 183-066 • 3 Address6 API Number. Stratigraphic r Service r, P.O. Box 100360,Anchorage,Alaska 99510 50-029-20948-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r I KRU 1Y-04 • 9 Property Designation(Lease Number). 10.Field/Pool(s) ADL 025641 • Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft)• Effective Depth MD(ft): Effective Depth TVD(ft) Plugs(measured) Junk(measured) 7420 - 6536 - 7296' - 6434' • none 7220' Casing Length Size MD TVD Burst Collapse CONDUCTOR 41 16 78' 78' SURFACE 2218 10.75" 2254' 2254' PRODUCTION 7362 7 7395' 6515' RECEIVED JAN 2 0 201 IW--S 1127115 AOGCC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size. Tubing Grade Tubing MD(ft) • 6797-6857,6908-6939,7122-7142,7158-7178 6028-6077,6119-6144,6293-6309,6322-6339 3.5 x 2.875 J-55 7047 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-CAMCO HRP-1-SP PACKER • MD=6658 TVD=5914 PACKER-CAMCO HRP-1-SP PACKER • MD=6894 TVD=6107 PACKER-BAKER FB-1 PACKER • MD=7019 TVD=6209 SSSV-CAMCO TRDP-1A-ENC SAFETY VALVE • MD=1821 TVD=1821 12 Attachments: Description Summary of Proposal r 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14 Estimated Date for Commencing Operations. 15. Well Status after proposed work: 2/1/2015 Oil r Gas r WDSPL r Suspended r 16 Verbal Approval. Date. VVINJ r GINJ r WAG r • Abandoned r Commission Representative GSTOR r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact John Peirce @ 265-6471 Email. John.W.Peirce@conocophillips com Printed Name John Peirce Title Sr. Wells Engineer Signature 7Phone:265-6471 Date 1'19 r 15 Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 5 " 02.c1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other I Spacing Exception Required? Yes ❑ No [( Subsequent Form Required / 0 - 4 a 4 (/ APPROVED BY / Approved by 904...4v9 -4"-- COMMISSIONER THE COMMISSION Date• / -36 — V'77-- /n- /5- Apprli ign alid t'2 Im months date of approval. Form 10-403 Revised 10/2012 it Submit Form aBAPPOs in up licF 22 - 4 2015 //,0 Af4/3 -/5 ii KUP INJ 1Y-04 • ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/DWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) c ,r.r,vr„lur,,, 500292094800 KUPARUK RIVER UNIT INJ 46.58 4,500.00 7,420.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 11-04,12/9/20141011 o9 AM SSSV:TRDP Last WO: 3/14/1987 41.01 5/10/1983 Verbal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,183.0 11/26/2014 Rev Reason:TAG lehallf 12/10/2014 - D Casing Strings HANGER;34.0 �[ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread lb ii, 4 CONDUCTOR 16 15.060 37.0 78.0 78.0 62.80 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 36.3 2,254.0 2,253.9 45.50 K-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I ' 'p' 1ur PRODUCTION 7 6.276 33.0 7,394.8 6,515.3 26.00 J-55 BUTT Tubing Strings CONDUCTOR;37.0-78.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 34.0 7,046.8 6,231.6 9.20 J-55 BTC AB-MOD 3.5"x2.875" Completion Details SAFETY VLV;1,820.8 lID No Top(ftKB) Top(ND)(ftKB) Top Inc)(') Item Des Com in)I 34.0 34.0 0.10 HANGER MCEVOY RETROFIT TUBING HANGER 3.500 1,820.8 1,820.7 0.63 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.813 6,632.9 5,893.5 34.64 SBR CAMCO OEJ SBR 2.875 SURFACE;36.3-2,254.0-, 6,657.5 5,913.8 34.60'PACKER CAMCO HRP-1-SP PACKER 2.867 GAS LIFT;2.519.46,779.8 6,014.2 35.28 BLAST RINGS RICKERT BLAST RINGS(3) 2.867 GAS LIFT;3,645.0 6,894.0 6,107.1 35.61 PACKER CAMCO HRP-1-SP PACKER 2.859 6,908.3 6,118.8 35.60 BLAST RINGS RICKERT BLAST RINGS(2) 2.867 GAS LIFT;4,119.6III 7,008.8 6,200.6 35.34 NIPPLE AVA BPL NIPPLE 2.750 • GAS LIFT;4,592.0 7,017.7 6,207.9 35.35 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY• 3.000 7,019.2 6,209.1 35.36 PACKER BAKER FB-1 PACKER 3.000 GAS LIFT;5.065.9 7,027.4 6,215.8 35.37 XO Reducing CROSSOVER 3.5 x 2.875 2.875 7,035.7 6,222.6 35.38 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5,540.4 • 7,046.0 6,231.0 35.39 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 7046'during 3.000 (PROF on 7/13/2008 GAS LIFT;5,965.3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inel GAS LIFT;6,398.0 Top)ft013) )ftKB) (°) Des Com Run Date ID(in) 6,965.0 6,164.9 35.43 PATCH Baker Patch 6960'to 7036'RKB set 8/17/2006. 8/17/2006 1.595 bottom spacer assy#1=31.11'OAL,spacer assy GAS LIFT;8,592.8 #2=22.40'OAL,upper packer 8 spacer assy #3=22.49'OAL[combined 76'OAL] SBR;6,632.9 �-`. 7,220.0 6,372.9 35.29 FISH Valve Assy&Nozzle 2'Double Check Valve Assy.& 4/11/1993 PACKER;6.657.5 Nozzle from Coil-Downhole r � Perforations&Slots INJECTION;6,699.0 Shot Dens INJECTION;6,770.9 Pa If Top(ND) Btm(TVD) (shotslf Irr'''. Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,797.0 6,857.0 6,028.2 6,077.0 C-4,C-3,1Y- 5/23/1983 12.0 APERF 5.5"SOS high density APERF;6797.0-,857.0- I II I 04 6,908.0 6,939.0 6,118.5 6,143.7 C-1,UNIT B, 5/23/1983 12.0 APERF 5.5"SOS high density 1Y-04 INJECTION;6,877.0 7,122.0 7,142.0 6,292.9 6,309.2 A-4,1Y-04 5/23/1983 12.0 RPERF 5.5"SOS high density 7,124.0 7,140.0 6,294.5 6,307.5 A-4,1Y-04 4/4/1993 4.0 (PERF 2 1/8"Enerjet;0 deg.Ph PACKER;6,694.0 7, 7,178.0 6,322.2 6,338.6 A-3,1Y-04 5/23/1983 12.0 APERF 5.5"SOS high densly Mandrelrel Inserts a APERF;6.908.0-,939.0- /1St atii N Top(ND) Valve Latch Port Size TRO Run Top(RKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com f 2,519.4 2,519.3 CAMCO KBUG 1 GAS UFT DMY BK 0.000 0.0 4/2/1993 . 2 3,645.0 3,605.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1993 INJECTION;6,971.7 'I. 3 4,119.6 4,009.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/2/1988 PATCH;6,985.04 4,592.0' 4,355.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 5 5,065.9 4,686.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 NIPPLE;7,008.86 5,540.4 5,028.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1993 7 5,985.3 5,370.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1993 SEAL ASSY;7,017.7 8 6,398.0 5,700.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/14/1987 PACKER;7,019.2 9 6,592.8 5,860.5 OTIS LBX 11/2 GAS LIFT DMY RM 0.000 0.0 10/11/2014 • 1 6,699.0 5,947.9 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 6/17/2003 Close • 0 d 1 6,770.9 6,006.9 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 11/2/2008 NIPPLE;7,035.7 i 1 !1 1 6,876.9 6,093.3 OTIS 2 LBX 11/2 INJ DMY RM 0.000 0.0 4/26/2009 SOS;7,5460 _ 1 6,971.7 6,170.4 CAMCO 3.5x 11/2 INJ DMY BK 0.000 0.0 7/10/1993 Close 3 1.5 d Notes:General&Safety RPERF;7,122.0-7,142.0 End Date Annotation IPERF;7,124.0-7.140.0 6/3/2006 NOTE:LEAKS FOUND IN TUBING @ 7001'&6982' - • 10/30/2008 NOTE:Bottom 6"of HFCV left in CSM @ 6771';severe erosion - 8/25/2009 NOTE:TECWEL LDL FOUND SUSPECTED CSG LEAK TO FORMATION @ 5760-5764 APERF;7.158.0.7.178.0- - 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;7,220.0 • PRODUCTION;33.0-7.394.8 Proposed 1Y-04 Retrievable Tubing Patch Installation An IPROF ran 9/1/07 in 1Y-04 showed that a 75% split was entering the C sand through an HFCV in GLM #11 at 6771' RKB. On 10/30/08, an attempt to pull the HFCV from GLM #11 resulted in retrieval of the top half of the valve, but the bottom 6" of the HFCV remained in the pocket. Subsequent Slickline efforts to fish the lower part of the badly eroded CV have been unsuccessful. A 4/28/09 (PROF showed an unregulated 92% split through GLM #11. Per this procedure it is proposed that a 20' retrievable tubing patch be set across the leaky GLM #11 at 6771' RKB to enhance the A sand spilt. ere is a rea ano Pier retrievable tubing patch that was set in 2006 across 2 other leaks (at 6982' and 7001' RKB) to the C sand. A retrievable patch set across the GLM #11 leak will preserve accessibility to the lower tubing patch should it need to be replaced in the future, or pulled in preparation for a possible RWO. Procedure: Slickline 1. Brush & Flush 3.5" tubing at 6740 - 6800' RKB in preparation for the tubing patch installation. Note: A 2.69" OD x 17.5' OAL dummy patch drifted to 6960' RKB on 12/26/14. This indicates that a tubing patch should drift to the tubing to target set depth. Min ID to drift above the patch target is 2.813" at 1820' RKB. Digital Slickline (DSL) or Eline: 9 2. RIH & set a 2.72" OD retrievable straddle packer at 6785' RKB in a full joint. POOH. DSL or Slickline: 3. RIH with run #2 assembly consisting from bottom to top of an anchor latch, spacer pipe, and an upper retrievable straddle packer (top). Latch into straddle packer at 6785' RKB and then set upper straddle packer at 6765' RKB. This leaves a -20' OAL patch at 6765 - 6785' RKB. 4. RIH with test plug and set it in the upper straddle packer at 6765' RKB. MITT to 2500 psi to verify integrity of the upper packer and the tubing above the patch. POOH with test plug. RD. Return 1Y-04 to PWI service and obtain a valid injection rate. JWP 1/19/2015 ge Project Well History File Page XHVZE This page identifies those items that were 'not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~_ ~_ - ~ ~2 ~) Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [3 Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Scanning Preparation BY: BEVERLY BREN Production Scanning Stage 1 Stage 2 IF NO IN STAGE '~, PAGE(S) DISCREPANCIES WERE FOUND: __ YES BY; BEVERLY BREN VINC~MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATFENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) NO NO DATE'I, /.~ ~ff'/lSl ~ RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IsI General Notes or Comments about this file: Quality Checked • ConocoPhillips Alaska P.O. BOX 100360 - ANCHORAGE, ALASKA 99510 -0360 � 1 December 30 2010 ` ;AN 4 1 ,Ui1 041_: a rk P. G "rrs® ssion Commissioner Dan Seamount ' nc orti e Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 gtONED ,SAN , 4 2.0\ 3 \ 0 9- Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23 24', 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein 1 - -- _ - ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 12/30/2010 1C,1E,1F,1G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft qal 1C-07A 50029205690100 2090290 3'2" n/a 3'2" Na 4.3 12/23/2010 1E-09 50029207200000 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" n/a 3'9" n/a 11.6 12/222010 1E-16 50029207770000 1821100 4' Na 4' n/a 13.7 12222010 1E -17 50029207930000 1821160 3'11" n/a 3'11" n/a 8.5 12/24/2010 , 1F-13 50029210200000 1831440 6" n/a 6" n/a 3 12/23/2010 1F-17 50029226570000 1960470 SF n/a 18" Na 7.65 12/23/2010 1F-20 50029226610000 1960530 6" n/a 20" n/a 6.1 12/23/2010 1G -13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y -01 50029209330000 1830500 SF Na 6" n/a 1.9 12/21/2010 1 Y 03 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF NA : -gr _ : = n/a "r - i.7° 12121/2010 1Y-11 50029209260000 1830410 9" n/ a 9" n/a 2.6 12/21/2010 1Y-12 50029209130000 1830260 4' n/a 4' n/a 8 12/21/2010 1Y-13 50029209030000 1830150 15" Na 15" n/a 1.7 12/21/2010 1Y-14 50029209100000 1830230 24" Na 24" n/a 1.7 12/21/2010 1Y-16 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21/2010 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. `L13V 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y -10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10. _0 Co c 18. 1Y -09 - AA 2B.051 issued 05/20/2010. 17. 1Y -08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 -AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly If apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1Q-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. From: Maunder, Thomas E (DOA) t: Tuesday, January 04, 2011 10:53 AM To: - Well Integrity Proj Cc: 'NS • oblem Well Supv' Subject: R . onocoPhillips Monthly Injector Report - Dec 2010 All, I am continuing to revie •e December Monthly Injector report. I am through a : al of 13 wells. I wanted to send this latest message du- • what I have found or not found on 1 Q -02B. A 1 continue to work through the report, I plan to send interim me .ges as I get 7 - 10 new wells reviewe•. Call or message with any questions. 13. 1 Q -02B - Well name is 1Q-02B. Well las . • 'ected 9/ • . I do not show having received any specific notification /request in June, 2010 regarding thi - . There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containing a . - • ent that you intend to return the well to injection and remove it from the waiver report in May. 12. 1 L -05 - AA 2B.054 issued 10/22/21 I. Well last injected 9/ : 11. 1 L -03A - Well name is 1 L -0 . • . Permit to Drill # is 199 -037. MITIA ed 09/25/2010. Well last injected 9/10. 10. 1G-01 - AA 2B.0 . issued 7/30/2008. 9. 1 F -16A - - I name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have pas -d since. Well last injected 4/ 0 I . AA 2B.018 was issued in October 2007, but no injection has occurred into the -II. Looking at the pre - re plot, it is shown that the IA pressure appears to have been bled off in October and No - • ber. Was 1/4/2011 • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM ���� To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907- 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 -659 -7000 #909 • ConocoPhillips Well 1Y-04 Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 3500 3000 - .° 2500 V) a 2000 1500 • 1000 500 0 09/10 10/10 11/10 12/10 01/11 Date PTD# 1830660 Failed MITIA casing leak. 7/3/2009 Well last injected 07/09. 0 • Conoco Phillips Well 1Y-04 Injection Data • Water Injection • Gas Injection 1 4000 3500 - 3000 - ° 2500 - c o. a 2000 2 1500 - 1000 - 500 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd 1 Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 31- Dec -10 0 0 1796 1750 400 30- Dec -10 0 0 1797 1750 400 29- Dec -10 0 0 1798 1750 400 28- Dec -10 0 0 1799 1750 400 27- Dec -10 0 0 1798 1750 400 26- Dec -10 0 0 1799 1750 400 25- Dec -10 0 0 1799 1750 400 24- Dec -10 0 0 1800 1750 400 23- Dec -10 0 0 1800 1750 400 22- Dec -10 0 0 1800 1750 400 21- Dec -10 0 0 1802 1750 400 20- Dec -10 0 0 1802 1750 400 19- Dec -10 0 0 1802 1750 400 18- Dec -10 0 0 1803 1750 400 17- Dec -10 0 0 1803 1750 400 16- Dec -10 0 0 1804 1750 400 15- Dec -10 0 0 1804 1750 400 14- Dec -10 0 0 1804 1750 400 13- Dec -10 0 0 1805 1750 400 12- Dec -10 0 0 1806 1750 400 11- Dec -10 0 0 1806 1750 400 10- Dec -10 0 0 1806 1750 400 9- Dec -10 0 0 1807 1750 400 8- Dec -10 0 0 1808 1750 400 7- Dec -10 0 0 1808 1750 400 6- Dec -10 0 0 1808 1750 400 5- Dec -10 0 0 1809 1750 400 s • 4- Dec -10 0 0 1810 1750 400 3- Dec -10 0 0 1811 1750 400 2- Dec -10 0 0 1811 1750 400 1- Dec -10 0 0 1812 1750 400 30- Nov -10 0 0 1812 1750 400 29- Nov -10 0 0 1813 1750 400 28- Nov -10 0 0 1814 1750 400 27- Nov -10 0 0 1815 1750 400 26- Nov -10 0 0 1816 1750 400 25- Nov -10 0 0 1816 1750 400 24- Nov -10 0 0 1817 1750 400 23- Nov -10 0 0 1818 1750 400 22- Nov -10 0 0 1819 1750 400 21- Nov -10 0 0 1819 1750 400 20- Nov -10 0 0 1819 1750 400 19- Nov -10 0 0 1820 1700 420 18- Nov -10 0 0 1821 1700 420 17- Nov -10 0 0 1822 1700 420 16- Nov -10 0 0 1821 1700 420 15- Nov -10 0 0 1821 1700 420 14- Nov -10 0 0 1823 1700 420 13- Nov -10 0 0 1824 1700 420 12- Nov -10 0 0 1825 1700 420 11- Nov -10 0 0 1826 1700 420 10- Nov -10 0 0 1826 1700 420 9- Nov -10 0 0 1827 1700 420 8- Nov -10 0 0 1828 1700 420 7- Nov -10 0 0 1829 1700 420 6- Nov -10 0 0 1829 1200 420 5- Nov -10 0 0 1830 1750 400 4- Nov -10 0 0 1831 1750 400 3- Nov -10 0 0 1831 1750 400 2- Nov -10 0 0 1831 1750 400 1- Nov -10 0 0 1833 1750 400 31- Oct -10 0 0 1834 1750 400 30- Oct -10 0 0 1836 1750 400 29- Oct -10 0 0 1838 1750 400 28- Oct -10 0 0 1838 1750 400 27- Oct -10 0 0 1838 1750 400 26- Oct -10 0 0 1839 1750 400 25- Oct -10 0 0 1840 1750 400 24- Oct -10 0 0 1840 1750 400 23- Oct -10 0 0 1840 1750 400 22- Oct -10 0 0 1841 1750 400 21- Oct -10 0 0 1842 1750 400 20- Oct -10 0 0 1842 1750 400 19- Oct -10 0 0 1843 1750 400 18- Oct -10 0 0 1844 1750 400 17- Oct -10 0 0 1844 1750 400 16- Oct -10 0 0 1844 1750 400 15- Oct -10 0 0 1845 1750 400 14- Oct -10 0 0 1846 1750 400 • • 13- Oct -10 0 0 1848 1750 400 12- Oct -10 0 0 1848 1750 400 11- Oct -10 0 0 1850 1750 400 10- Oct -10 0 0 1850 1750 400 9- Oct -10 0 0 1852 1750 400 8- Oct -10 0 0 1851 1750 400 7- Oct -10 0 0 1853 1750 400 6- Oct -10 0 0 1853 1750 400 5- Oct -10 0 0 1854 1750 400 4- Oct -10 0 0 1855 1750 400 3- Oct -10 0 0 1856 1750 400 2- Oct -10 0 0 1856 1750 400 S WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 23, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1Y -04 Run Date: 7/31/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y -04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 20948 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 2-0.-1 3" 6900 Arctic Blvd. Anchorage, Alaska 99518 its Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barr @h4ihu kor .,com.,, Date: NOV o 5 2009 Signed: I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 19, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detechon Log: 1Y-04 Run Date: 7/26/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y -04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 20948 -00 NC 200s km '�,WI'Lr�r' LrW�✓ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 11).3-066 6900 Arctic Blvd. Anchorage, Alaska 99518 //A Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barretohallbton com 7 Date: NOV 0 5 7009 Signed: lilt Eft! Uchoms l` ~ ~ \ --- -- ~:= PROAcrivE D'u~ynosric SeRVicES, Inc. ~ . ~GL~ ~~G TR~4/I~~M/TT,4L To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hote/Mechanicaf Logs and/orTubing tnspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal fetter to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 S Fax: (907) 245-8952 1 j Leak Detection - WLD 24Aug-09 1 Y-04 EDE 50-029-20948-00 2) ~~~r~~~~~ ~i ~'`,! ~. ~ 20~~ (~ 2 ~ t ~ 3r~~ ~~~('°~° Signed : Date : , _ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. IMTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAlL: _, _ ;..-%t `:? '~ r> WEBSITE ,~!_ , ";, C:`.aocuments and Setangs`~.Owner~Desktop~Truumit_Conoco.docx • MEMORANDUM TO: Jim Regg ~~~ -?(3t j 0~ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 31, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-04 KUPARiJK RIV IJNIT 1 Y-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~' Comm Well Name: KUPARUK RIV iJNIT 1Y-04 API Well Number: 50-029-20948-00-0o Inspector Name: Lou Grimaldi Insp Num: mitLG090703101618 Permit Number: 183-066-0 ~ Inspection Date: ~~3~2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lY-oa Type Inj. ~"~ TVD 5914 jA ; 380 zszo 23to zz~o z2ao P.T.D 1830660 TypeTest SPT Test psi 252~ ' ~E~l 170 260 200 190 190 Interval 4YRTST p~ F ~ Tubing 1900 1900 ]900 1900 1900 Notes: 3.1 bbl's pumped. Questionable four year test . ~ J•.lry~. -l~~preSSr~,2. f5"U~~; ~~~ y~~~~ r-. ot. ~),''~~r(~:'. x p ~.~ 1. . » ... _.. Friday, July 31, 2009 Page 1 of 1 ! MEMORANDUM To: Jim Regg P.L Supervisor ~~''Cj~ 7~~, U~ C~ FROM: Lou Grimaldi Petroleum Inspector ! State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-04 KUPARi1K RIV iJNIT 1Y-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~'~ Comm Well Name: KUPARUK RN LTNIT 1Y-04 API Well Number: 50-029-20948-00-0o Inspector Name: Lou Grimaidi Insp Num: mitLG090703144658 Permit Number: 183-066-0 ,/ Inspection Date: ~~3/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ 1Y-04 Type Inj. w ~j'~ I 5914 IA 600 2500 2300 2100 2090 P.T.D 1830660 TypeTest SPT Test psi 2500 QA 200 245 200 180 170 Inte~.Va~ 4YRTST p~' F `~ Tubing 1890 1890 1890 1890 1895 NOtes: 2nd test on this well today (mitLG090703101618). 3.6 bbl's pumped. Excessive loss from initial pressure (400 psi) although third period IA ~ pressure leveled out. ~/V~..~'~' ~it'.~rvVJ'-L ~S~C`_)~.~, ,"~~, ~ a ~ `. .~ . r `,'~. , ._ E~ ti> ;~+-. Thursday, July 30, 2009 Page 1 of 1 CJ ~~~~ ~ :T ,~, ~, ~ i~ ~ ~ ~~ ~~1~~~~~I~'~ ~~Z. '~~o A~asac~ ~il and ~as ~~r~serv~c~~~ ~C~~i~n. ~,~~~,; ~'~?risii~~ 1~~1ah~~~,~? ~33 ~~ys~ 7~~~ t~v~~aa~, ~~a~'t~, 3 ~~ ~-'~~~?~o~ag~, Al~,s:~a 995~1 RE: Plug Setting Record: 1Y-04 ,~~a~~ 27, ~~i~9 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 ~'-04 Digital Data in LAS format .. , ,~f ~~',E;, ~;: `: ~J~'~~ 50-029-20948-00 ' ~ ` i` ~ ~ ~ ~ ~s3 -oc~c~ 1~ 3 ~~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafaei. b arreto @hal Iiburton. com ~, ~ ' ~1 Date: Signed: ~~~ ~- ~ • r-~~,, 1Y -04 (PTD183 -066) Report of fa. MITIA Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, July 05, 2009 9:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1Y -04 (PTD183 -066) Report of failed MITIA Attachments: 1Y -04 schematic.pdf; 1Y -04 90 day TIO plot.jpg Tom, Jim Kuparuk water injector 1Y -04 (PTD183 -066) failed an MITIA on 07/03/09 during the witnessed pad MITIA's. The TIO prior to the test was 1900/380/170. The well will be added to the monthly report. It is ConocoPhillips intention to leave the well on water injection and diagnostics are in progress. Pending the outcome of the diagnostics, another witnessed MITIA will be scheduled or an application for an AA will be submitted to continue water injection. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters JAN ( 20i, Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 «1Y -04 schematic.pdf» «1Y -04 90 day TIO plot.jpg» 1/4/2011 ) HI I Z. T/I/O Plot - iy_04 IIIrtsigI,111111111141orif . 'I I 1 i ,u.1 le, r, I , I. i ill111.11 „.............,.... el\ , d 01 0 .... N 11110/ Z A -...,,..„.. ii; i . 1 ii / .1.,......,---,-, 1 1 I • t ir V ,,........., ,, , ...... ii i k I , a 4 I / / ■ . ■ I I ' ( • / ..... .... , -Apr-09 01-May-09 14 27-May-09 09 22-.11, Date ~i~r~~~~~~~ir~ NO. 5203 -------~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,., ,~,,, ~ ii:~ Log Description 04/30/09 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3F-03 ANHY-00070 INJECTIO ' 2D-03 1 E-29 3G-13 3F-18 ANHY-00075 604C-00030 ANHY-00079 B04C-00031 N PROFILE - ~ ~ PRODUCTION PROFILE - ~ PRODUCTION PROFILE 1 9 INJECTION PROFILE ~ _ c/ PRO 04/04/09 04/10/09 04/14/09 04/15/09 1 1 1 1 iD-117 B14B-00027 DUCTION PROFILE / INJECTION P 04/15/09 1 1D-128 1H-21 iD-120 2K-22 1E-15 AYS4-00057 8146-00028 AYS4-00058 AYS4-00059 AYS4-00061 ROFILE ~ - ~-- INJECTION PROFILE PRODUCTION PROFILE _ L INJECTION PROFILE IBP/SBHP - INJECTION ' 04/16/09 04/16/09 04/17/09 04/17/09 04/18/09 1 1 1 1 1 1Y-04 3F-02 AYS4-00071 AYS4-00063 PROFILE ~, INJECTION PROFILE PRODUCTION PROFILE ~ - 04/20/09 04/28/09 04/22/09 1 t 1 1 G-04 iR-03A B14B-00036 AYS4-00063 SBHP SURVEY '~, e C~ SBHP SURVEY ~ } -t ~+ ~~(~ _~~1 a ~ 9C/( 04/23/09 04/23/09 1 1 iG-O6 _ o c~ B14B-00035 SBHP SURVEY ~~ 1~3~ _~~ ( ~~/•°~ 04/23/09 iR-10 B14B 0 ~ 1 - 0031 SBHP SURVEY - ~~ ~ 04/20/09 1 2F-02 1R-15 AYS4-00060 B14B-00032 INJECTION PROFILE v C - !b`6 ~l SBHP SURVEY; - ~ `"' ~"} L 04/19/09 04/20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~~~~6~~6r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth c~~ f, NO.4792 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 07/24/08 • Well Job # Log Description Date BL Color CD 1A-06 12080402 INJECTION PROFILE - ( 07/06/08 1 1 3C-17 11964626 SFRT C~~- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE ~ 07/13/08 1 1 1G-06 12061729 INJECTION PROFILE a ~ 07/13/08 1 1 iF-06 12096506 PRODUCTION PROFILE -~ 07/14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (o (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY v2C Co - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ _. 07/16/08 1 1 1F-O6 12096510 PRODUCTION PROFILE -/C/ 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE (> 07/18/08 1 1 3J-17 12096514 SBHP SURVEY g I~~ ~- 07/20/08 1 1 3J-07A 12097409 0 SBHP SURVEY O /_~~~ ®(~(~'~~ 07/20/08 1 1 3C-15A 12097406 USIT / '~ 07/17/08 1 1 2A-OS 12096512 SCMT - 07/19/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. %,~,k~-e~'e.. -- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # k _. ; i? ~9~~~ ~~~ ~ ~ ZQ~7 N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~; Y_''~~ ~ ~ ~~ `~' \~~ Log Description Date . BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ~ G - 08/08/07 1 1B-14 11837493 PRODUCTION PROFILE - ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE (~- 08-30107 1 1Y-18 11837499 PRODUCTION PROFILE C 08/30/07 1 1G-14 11839652 INJECTION PROFILE ~. ~j- ~ 08131/07 1 1A-01 N/A USIT 08/31/07 1 1Y-04 11839653 INJECTION PROFILE f 5 09/01/07 1 1Y-32 11839655 PRODUCTION PROFILE ~ - 09/02/07 1 27-TAB-01 11839656 INJECTION PROFILE C - - 09/03/07 1 2K-25 11846439 INJECTION PROFILE U = 1 09/06/07 1 2K-18 11846440 INJECTION PROFILE J -1 09!07107 1 18-18 11846441 PRODUCTION PROFILE ~/ - 09/08/07 1 2T-20 11846442 PRODUCTION PROFILE ~' s - 09/09107 1 2N-310 11850433 SONIC SCANNER ~b'~-(~ c~ 09/16/07 1 2N-310 11850433 SONIC SCANNER-FMI `~ - C~`~, 09116/07 1 1J-176 11846443 USIT '~ - 09/17/07 1 1 E-29 NIA UCI ~ - ~ 09/19/07 1 3F-21 11837503 RST/ WFL - 09/20/07 1 2B-10 11839661 INJECTION PROFILE ~ - 09122!07 1 1G-05 11837506 INJECTION PROFILE v2C 09/23/07 1 2H-13 11839662 INJECTION PROFIL L - 09123107 1 16-05 11837508 INJECTION PROFILE Lam' 09/24/07 1 3H-08 11839663 PRODUCTION PROFILE - (j 09/24/07 1 1Y-31 11839664 PRODUCTION PROFILE J ~i - 09/25107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USiT - l~ 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER '~~ - 09/28107 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE (~ 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Wednesday, July 19, 2006 kef, ¿;¡ 7(z;¿J\, SUBJECT: Mechanical Integrity Tests ,,{ 1. " ~,,~ CONOCOPHILLIPS ALASKA INC IY-04 KUPARUK RIV UNIT I Y-04 \ q,'b"' 010 /¿¡ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SD¡2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lY-04 API Well Number 50-029-20948-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0607181 04708 Permit Number: 183-066-0 Inspection Date: 7/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IY-04 ¡Type Inj. i w i TVD I ! I -¡--- Well 5914 IA 1060 2170 2050 2030 I i P.T. 1830660 ITypeTest! SPT ! Test psi 1500 i OA , 190 I 190 I 190 190 I I Interval 4YRTST P/F p Tubing i 1315 i 1345 I 1345 1345 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity, ,' "". ~,,,,V·-·f"" ' ~.)\,¡¡.tJ\" \;. "C,~.: '.f ç <,;,.' Wednesday, July 19,2006 Page 1 of 1 RECE\VED 06/13/06 Scblunlbepgep o CoG /)./ \~'-") Ù~~ ,JUN 1 4: 70GB NO. 3850 I\I~ Oil Comml~~ioo Anchof~'}ê Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .- ~) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ", ' 'r.:::'~" ~C^,N~t..~ Field: Kuparuk Well Job # Log Description Date BL Color CD ! 1;- 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1 R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 . 11213760 PRODUCTION PROFILE W/DEFT 05/31/06 1 1 R-07 11249912 PRODUCTION PROFILE 06/07/06 1 1F-12 11320981 PRODUCTION PROFILE W/DEFT 06/06106 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE W/DEFT OS/25/06 1 2A-22 11213756 LDL OS/27/06 1 1Y-04 11320980 LDL 06/03/06 1 2Z-02 (REDdf 11235362 INJECTION PROFILE OS/28/06 1 1 H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13 (REDO) 11320976 LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06/11/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r. j7~"",~__" C) / I Lf !(~ e e Schlumbel'gBI' NO. 3456 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/24/05 r@:3~O~ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~r"(jl.ûl!¡.1 j\Í ~ [: ~ i:'. fJ f,; ¡i ¿n 0, r¡ t:,' l~~i -to... ~-.. .¡;,~...,_h"'" \.) '=- f 'L' ~ u~ Field: Well Job# Log Description Date BL 1 E-18 Jj" 3 -. C ¡ (" 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 I SJ.. -,1 J'l 11047354 PRODUCTION PROFILE W/DEFT 07/31/05 1 1Y-06A 19T-1 J 'i 11015712 PRODUCTION PROFILE W/DEFT 08/05/05 1 3J-06 ¡ gS-- - ).. i 'i 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 i ''}3 - 010 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1B-10 J9í-jJ># 11056671 PRODUCTION PROFILE W/DEFT - 08/12105 1 3G-10 jqt.-. c:iJ-t 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } qç-- Olö 11015717 INJECTION PROFILE 08/10/05 1 2X-06 S ~ -JI D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 I J ~ ·~/)3 11015710 INJECTION PROFILE 08/04/05 1 1 Y -04 I J 3 -- G G. ~ 11047351 INJECTION PROFILE (REDO) 07/27/05 1 SIGNED: µ. oil; DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD -/ -' ,.-, -7~ .~\;~. - ~..Q. '"). " - ~';"I.J \ ~~:.) . Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ;./ 2N-305JðO-ì Jç J .2N-308 (q<\ -ûit .I2N-317 I q 3- NJ V~2G-06 13~(-C.&.). ,,/ 1 Y -04 Î 8 ') - f¡ ~ l J3J-10 iyi-J..\~ ..I2U-10 I~) - t )\1 c.'1C-178 ~c)- t'-1( Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 S!='Il~If\.iE~C' CLI) n fl: ?Unn¡: vvnnH'\'l - ~I:~ 'J U b· uJ Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE V í (. MULTI-FINGER CALIPER LOG PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE WIDEFT /,1 / jn ('''.! . J ./! I I ( , ; f ./1 N/ N. f.... If / /~L1,,,;,/ / \/1 /iu II -." .... SIGNED: Date 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 08/03/05 NO. 3443 1%3 - O{¡¡(p Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color '-' CD 1 1 1 1 1 1 1 1 -' ..-~.~ ~... ~'i\ DATE: ¡;/'"-- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: ¡::<2ci1 b!Z'ì.!04 Jim Regg P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT I Y-04 Insp Num: mitCS040619212600 Rellnsp Num: State of Alaska Alaska Oil and Gas Conserntion Commission DATE: Wednesday. June 23, 2004 SlIBJECT: t\kchamcallntegm)' Tests CONOCOPHILLlPS A1ASK...o\ fNC 1 Y -(14 KUPARUK RIV UNlT 1 Y-04 Src: Inspector NON-CONFIDENTIAL API \Vell Number: 50-029-20948-00-00 Permit Number: 183-066-0 Re\'iewed By: . . 'Í';r'-- P.I. Supn '-J{; Comm Inspector Name: Chuck Scheve Inspection Date: 6/19/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I Y-04 Type Inj. P TVD 6535 IA 1100 2110 2000 1980 P.T. 1830660 TypeTest SPT Test psi 1478.5 OA 180 180 180 180 Interval ~Y'RTST PIF P Tubing 2350 2350 nso 2350 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 23, 2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie HeUsser ^~? DATE: July 6, 2001 Commissioner ~O'~'-'- '~''fl'Y~~ SUBJECT= Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska Inc. P.I. Supervisor _~.~\..[\~, ,~\ 1Y Pad 1Y-03, 1Y-04, 1Y-14 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON._._: CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we.I w~ ITvpe Inj. I ~ '1 'r;v.D. I' 5~? I T.~.~ I' ~7~ I.. 375°' I 375o "11.:~7~ I~n~'al 4: P.T.D.i ,~&30610 ITypetestl, P .ITestPsil 1472 [Casing 1. 185o. I 23so. I 2380 I 2,350, I P/F I P-- Nails: ' - Wellt ' 'i'Y-04 I Type Inj:l S "i T.V,o'. i ~14 I' Ta3ing ! 2500 I '2500.. I 2 ..~00 I_ ~500'l~.te~l 4 P.T.D.I 18,30660 ITyp~i. P I'r~l .14,7.~) Ic.~..gl ~ 1237512375..[ 23501 P/F I P Notes: w;~l 1¥-~4 If~.j.l' 's "! T.V~O. ! '~' I.T.U~,I 2r~. 1',',.2.~. I 2~5° I '2.~ I!,,,~1 4" -P.T.D-I 1830230 IT,~, t.~l ..P . I,r-"p~i ~4z~, I c~I ~0. I, ~,?~0 I ~74°1 !740. I P~ I P "we, I P:,T.D.I Notes: ' Well~ ' P~T.D.i Notes: I T~.e.'..j.I ,'.. I,,T-v-D- I rTu~ngl I, .' "I. ' ','1. I,r~all' ' Typetest,! ' IT,est psi]' I.C~r~ I I , . I ,. I.., I P/F I ITypelnj. I' IT.V.D.I ' rf~ I II!I I' I I .... l'.t,~,lI I I IT. Tp~,t~i ' I'~,'~_'i .... ! C~.~ Ii .' I'.' ', i! I I P/F I Type INJ. Fluid Codes F = FRESH WATER INJ. O = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactiv~ Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Tests Details Friday~ Ju!¥ 6, 2001: I traveled to Phillips Alaska Inc.'s IY Pad and witnessed 4-year MIT's on wells IY-03, 1Y-04 and 1Y-14. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all three wells passing the MIT's. Summa,fy: I witnessed successful MIT's on PAl's wells 1Y-03, 1Y-04 and 1Y-14 in the Kuparuk River Field / KRU. M.I.T.'s performed: _3 Attachments: Number of Failures: _0 Total Time dudng tests: 2 hrs, cc; MIT report form 5112/00 L.G. MIT 1Y Pad KRU 7-6-01 JJ.xls 7/16/01 Alaska Oil ~as Canser,,ation Cammissian 300i Porcupine Drive Anchorage, Ala.s~a §§S01-3192. 907-279-14.,., The following data is hereby acknowledged as being received: " 11 Received Dated: ARCO Alaska, Inc.:' Post Office B~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL 1 H-01 1H-09 1H-10 1 H- 11 1H-1 7 z'~ Q-04 O-04 1Y-03 ,~ 5.-~1Y-04 ACTION Perforate Stimulate Stimulate Perforate Stimulate Stimulate Stimulate Stimulate Perforate Other (conversion) Other (conversion) If you have any questions, please call me at 263-4241. · Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED NOV 1 2 199 Alaska Oil & Gas ~m$. Commisslen ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ OIL AND ~ CONSERVATION COMMIS,, JN ._ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Repair well Perforate Other 12. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 211' FNL, 1973' FWL, Sec 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1616' FEL, Sec 36, T12N, R9E, UM At effective depth 1458' FSL, 1389' FEL, Sec 36, T12N, R9E, UM At total depth 1502' FNL, 1332' FEL~ Sec 36~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7 4 2 0 feet true vertical 6535 feet 6. Datum elevation (DF or KB) RKB lO2 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-04 9. Permit number/approval number 83-66/93 -250 10. APl number so-029-20948 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7 2 9 6 feet true vertical 6434 feet Junk (measured) None 13. Casing Length Structural Conductor 7 8' Surface 2 2 51 ' Intermediate Production 7 3 6 2' Liner Perforation depth: measured 6797'-6857', true vertical 6028'-6076', Tubing (size, grade, and measured depth) Size Cemented 1 6" 271 SX AS I 1 0-3/4'" 900 SX Fondu & 250 SX PFC 7" 950 SX Class G & 250 SX PFC 6908'-6939', 7122'-7142', 6118'-6143', 6292'-6308', Measured depth True vertical depth 78' 78' 2254' 2254' 7395' 6515' 7158'-7178', 6322'-6338' 7124'-7140' 3.5", 9.2#, J-55 @ 7027' & 2-7/8", 9.2#, J-55 @ 7045' Packers and SSSV (type and measured depth) PKR: Camco HRP-I-SP @ 6650' & 6886", Baker FB-1 @ 7011; SSSV: Camco TRDP-1A-ENC ~ 1813' Stimulation or cement squeeze summary RECEIVED Converted well from oil producer to water injector on 10/25/93. Intervals treated (measured) N/A NOV 1 2 1993 Treatment description including volumes used and final pressure N/A Alaska .0it & gas Cons. Commission 14. Re_oresentative Daily Average Production or Injection Data ,~rag8 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 729 646 2188 1365 214 Subsecluent to operation 0 0 5900 1500 2183 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas Suspended Service MWAG In!. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Date //'''6~''' f~ SUBMIT IN DUPLICATE F, DOS MORNiNg WL=.LL REPORT FOR .... ?/93 DR ILLS ]]7'E 1Y PRODUC-F 'r ON, WELL. a ! ..,-,, I U.::,; .... .,.----.ri._. 7" ! ,r.) ,, WC HZ:S C FTP FTT % PPM PSI PSI 0 OM OM 91 65 i750 0 17,5 1 ~';0 80M 4 65 4 ,_,0 ,4..z ,_, 176 i75M 1tOM 0 0 1010 300 01'i OM 0 0 0 0 01'1 OM 0 0 0 0 OM OM 0 0 0 0 OM OM 0 0 200 40 ON 01'1 0 0 0 0 01'1 01'1 0 0 0 0 !76 182 i 14 80 85 ,950 820 176 174 i28 70 40 1i00 620 0 OM OM 0 0 0 0 0 OM OM 0 0 720 330 i5 1746 i01 15 713 103 80 0 OM 01,1 0 W Z S E 0 T C. HOKE L N A OR L. E T 6. B SI &APR ~ C PR ...~ B SI 0 o B SI 0 '_} B SI 0 "~ B SI 0 :3 B SI 0 ~q-~ SI 0 ~& B PR s~B SI :9 B PR :d'B PR ,,~ B PR :~ B SI 55 1750R =00 80 700 0 0 0 0 15 713 143 84 110 1340 1650R 0 OM OM 0 0 480 700 RECEIVED ~o~k~ u. ~ Gas Cons. Commission Anchorage ,:~A5 L. iF'T STATUS igOR :::- 30000 "ii 'ii DATA 6'; A S 0 ' '"' t.~c) I N,.) OP-r [::~P-r' METER VOL_ RATE READINO MSCF MSCFD R[]OTS 0 0 0 0 600M 0 0 1071 0 0 0 0 0 0 0 0 17 0 0 0 0 0 0 0 0 0 0 0 758 7i5 0 770 0 0 OM 0 0 OM 0 0 72 0 0 0 0 0 0 0 0 0 0 0 0 0 O. ',7.) 0 ,,':) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 ' 0 0 0 0 0 0 0.0 0.0 0.0 0.0 O. 0 C :-i M 0 F;.: I D ':-3 N E ; ? ..'~ ,.'.)0 75 ,'; .? 0,:.} 0 "'" C.' 000 '" ;i ;"O ;'j 0 ;7; 'i. 0 0 0 .:]; ,70 Q0 Z! 400 0 ;:: 400 0 ;:' 4 00 C: ,7) i 30 2":? ('.' ! .3() ,w~,, .... ) ": 0 Q ;" '- . "T x_ ..¢ '-, ,$ ,'h ',7) (} 000 0 '.'_) (') 0 'D 0 3400 0 0000 0 Lit 400 1 i OTALS: 3288 715 INOECTION WELL S.ATU= Z S O T CHOKE N A OR E T % 7" i0" INd CSg CSG PSI FTT PSI PSI INOECTION VOL.UME~= WATER RECMD gAS INO IN,) INO METER VOL RATE VOL READIN~ BBL. S BWPD MMSCF "' DA 7' =I A C H M 0 R I D S N E PW .PW 3 B PW 5 A SI .MI 8 g MI SI 0 B SI PW 2 B PW 4 A PW ~ !3 PW 100 2300M 145M 1040 750 100 2300M 140M 540 0 100 2300M 145M !20o ~ !00 2300M !45M 1500 !20 0 OM OM 1500 500W 100 2760 101 0 !00 100 2670 101 50 0 0 OM OM O* 0 0 OM OM O* 0 100 214.0 146 2600R 1350- !00 2122 145 1020 1200R 100 1300M i5M 0 0 44 2350M 140M 1500 740 100 2350 142M 1300R 550 0 5000M 4432~ 0.000 0 5000M 6281- 0.000 0 5000M O* 0.000 0 5000M O* 0.000 0 0 O~ 0.000 0 0 0 4.292 0 0 0 6.756 0 OM O* 0.000 0 0 O* 0.000 0 5606 I041 0.000 160010 3856 6264~ 0.000 0 7500M 1 '742 O. 000 157655 2510M O* O. 000 0 7500M 2010 O. 000 0000 0 0000 0 0000 0 - oo6 2400 70 0000 0 0000 0 2400 36 2400 36 0000 () 0000 0 2400 36 0000 0 0000 0 'OTALS' SWI' 0 + PWI' 46972 = ,16972 21770 ll. Oq-8 ,N * AFTER THE RECOMMENDED WATER iNJECTION RATE iNDICATES THAT THE cE[.L SHOULD BE WIDE OPEN REGARDLESS OF THE LISTED RECOMMENDED RATE. ARco Alaska, Inci Post Office 'Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 13, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached irlltriplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Y-04 Y-06 Y-1 6 Action Change Program Change Program Change Program Anticipated Start Date 9/93 9/93 9/93 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments ARCO Alaska_ Inc. is a Subsidiary of AllanticRichfieldCompany AR3!; ;~r~03 (; STATE OF ALASKA A~_ .dKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown m Re-enter suspended well Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program X_~ Pull tubing __ Variance Perforate __ Other 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X~ 4. Location of well at surface 211' FNL, 1973' FWL, Sec. 1, TllN, R9E, UM At top of productive interval 1277' FSL, 1616' FEL, Sec. 36, T12N, At effective depth 1458' FSL, 1389' FEL, Sec. 36, T12N, At total depth 1502' FSL~ 1332' FEL, Sec. 36, T12N, 12. Present well condition summary Total Depth: measured 7 true vertical 6 Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 1 02 7. Unit or Property name Kuparuk River Unit feet Casing Length Structural Conductor 7 8' Surface 2 2 1 7' Intermediate Production 7 3 61 ' Liner Perforation depth: measured 6797'-6857', true vertical 6028'-6076', Tubing (size, grade, and measured depth) 3-1/2", 9.2#/ft., J-55 @ 7027' & Packers and SSSV (type and measured depth) R9E, UM R9E, UM R9E, UM 42O 535 7296 6434 Size 16" feet feet 8. Well number 1Y-04 9. Permit number 83-66 10. APl number 50-.029-20948 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None feet feet Junk (measured) 1.5" DV and 1.75" coil tubing nozzle in Rathole Cemented Measured depth True vertical depth 271 SX AS I 78' 78' 10o3/4" 900SXFondu& 250 SX Permafrost C 7" 950 SX Class G & 250 SX Permafrost C 2254' 2254' 7394' 6908°-6939', 7122'-7142', 7158'-7178' 6118'-6143', 6292'-6308', 6322'-6338' 2-7/8", 6.5#/ft., J-55 @ 7027'-7045' 6515' RECEIVE SEP ! ? 1.99: ¢~iaska Oil & Aneh0rag,, PKR: Camco HRP-1-SP @ 6886' & 6650',Baker FB-1 @ 7011', SSSV: Camco TRDP-1A-ENC @ 1813' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ Connvert oil producer to MWAG injector. 15. 14. Estimated date for commencing operation September 1993 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil Gas Suspended __ Service MWAG Injector 17. I here!;~y~ certify_ that the forl~going is true and correct to the best of my knowledge. Si,ned'~/j~~' ~ TitleSenior Engineeer FOR COMMISSION USE ONLY Conditions of approval: Plug integrity __ Mechanical Integrity Test Approved by order of the Commission Form 10-403 Rev 06/15/88 Notify Commission so representative may witness JApprovaJ.-N°'~ BOP Test _ Location clearance __ J Subsequent form require 10- Origina! $;,gned By __ _2- ). )-2;~, _ David, W. Johnston Commis~ion-e~ SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 1Y-04 ARCO Alaska requests approval to convert Well 1Y-04 from an oil producer to an MWAG injector. This well will be operated as a Class II UlC well in compliance with Area Injection Order No. 2. Water alternating with miscible gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6028' and 6338' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVEE SEP ! 7 1.993 Anch0rage STATE Of ALASKA ~ OIL AND GAS ~SERVATION COMMI~ION REPORT OF SU 1. Operations Performed: Operation ~ ~ Stimulate __ Plugging Perforate Pull tubing Alter Casing Repair well Other 5. Type of Well: 6. Datum elevation (DF or Development X__ 2. Name of Operator ARCO Alaska. Inc. Exploratory RKB 102 feet 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 211' FNL, 1973' FWL, Sec. 1, T11N, RgE, UM At top of productive interval 1277' FSL, 1616' FEL, Sec. 36, T12N, R9E, UM At effective depth 1458' FSL, 1389' FEL, Sec. 36, T12N, R9E, UM At total depth 1502' FSL, 1332' FEL, Sec. 36~ T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7 4 2 0 feet true vertical 6535 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-04 9. Permit number/approval number 83-66 10. APl number 50-029-20948 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7 2 9 6 feet true vertical 6434 feet Junk (measured) None 13. 14. Casing Length Size Structural Conductor 7 8' 1 6" Surface 2251' 10 Intermediate Production 73 6 2' 7" Liner Perforation depth: measured 6797'-6857', true vertical 6028'-6076', Cemented Measured depth True vertical depth 271 Sx AS I 78' 78' 3/4" 900 Sx Fondu & 2254' 2254' 250 Sx PFC 950 Sx Class G & 7395' 651 5' 250 Sx PFC 6908'-6939', 7122'-7142', 6118'-6143', 6292'-6308', 7158'-7178' 6322'-6338' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7047' Packers and SSSV (type and measured depth) PKR: Camco HRP-1-SP @ 8692',HRP-1-SP @ 8692',Baker FB-1 @ 7019'; SSSV: CAMCO TRDP-1A- ENC @ 1821' RECEIVED J U N 2 5 1993 Alaska OJJ & Gas Cons. Commission Stimulation or cement squeeze summary Reperforated "A" sands on 4/4/93. Intervals treated (measured) 7124'-7140' Treatment description including volumes used and final pressure 4 SPF @ 0° phasing. Re_~resentative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 200 120 0 950 180 Subsequent to operation 200 120 0 950 180 15. Attachments ~ 16. Status of well classification as: I Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidian/of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRAC~O'R RI~MARKS IPBDT FIELD-DISTRICT-STATE IDASS OPERATION AT REPORT TIME AFe: 9~Z~8¢ / 8o~z3 · £=r. Co¢7': a ~ 400. ~ DATE KUPARuK PFT~(3~ cUM c,,,,,,,,,,- ...... ! Alaska CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather t TemP'Rennrt ,,. IchIll FactOr vlslbillty,,,~ __.__. IWInd vel' ~...... Isigned ..... STATE Of ALASKA ~-~' ALASKA OILAND GAS CONSERVATION COMMI,,~ION REPORT OF SUNDRY WELL OPERATIONS · Operation Shutdown~ Stimulate ~ Plugging _ f Perforate _.__ '-'~.,~ I Operati°nsPerf°rmed: tubingPull Altercasing Repair well Other__ 5. Type of Well: 6. Datum elevation (DF or KB) ~/~1 \1 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 211' FNL, 1973' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1616' FEL, Sec. 36, T12N, R9E, UM At effective depth 1458' FSL, 1389' FEL, Sec. 36, T12N, R9E, UM At total depth 1502' FSL, 1332' FEL, Sec. 36r T12Nr R9E~ UM 12. Present well condition summary Total Depth: measured 7 4 2 0 feet true vertical 6535 feet RKB 102 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-04 9. Permit number/approval number 83-66 10. APl number so-029-20948 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7 2 9 6 feet true vertical 6434 feet Junk (measured) Nolle 13. Casing Length Size Structural Conductor 7 8' 1 6" Surface 2251' 10 Intermediate Production 73 6 2' 7" Liner Perforation depth: measured 6797'-6857', true vertical 6028'-6076', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7047' Cemented 271 Sx AS I 3/4" 900 Sx Fondu & 250 Sx PFC 950 Sx Class G & 250 Sx PFC 6908'-6939', 7122'-7142', 6118'-6143', 6292'-6308', Measured depth True verti~l depth 78' 78' 2254' 2254' 7395' 6515' 7158'-7178' 6322'-6338' Naska 0JJ & ~ Packers and SSSV (type and measured depth) ~ PKR: Camco HRP-1-SP @ 8692',HRP-1-SP @ 8692',Baker FB-1 @ 7019'; SSSV: CAMCO TRDP-1A,_,,,,r~e1821' Stimulation or cement squeeze summary Refractured "A" sands on 4/9/93. Intervals treated (measured) 7122'-7142' Treatment description including volumes used and final pressure Pumped 22 Mlbs of 16/20 & 48 Mlbs of 12/18 carbolite into formation, 5500 psi, 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 200 120 0 950 180 Subsequent to operation 250 170 110 1400 190 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil .X Gas Suspended 'i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidlar7 of Atlantic Richfield Company WELL SERVICE REPORT WELL PBDT ?>/- ¥ ~~ ' CONTRACTOR RE'"/ 'KSI~AR ('/~' */ IFIELD - DISTRICT- STATE IOPEI~ATION AT REPORT TIME - - L.. L.. J.,/ JUN ~ ~ 1993 Alas/{a Oil & Ga, [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReDort ITemp' o= Ichill FactOr vlsibility0c _,,.. Iwind vel' ~...,. ISlgn.-,ed ARCO Alaska, Inc. Date: July 8, 1988 Transmittal #: 7218 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Y-04 Kuparuk Well Pressure Report 7-0 1 - 8 8 'C'Sand 2 T- 1 7 Kuparuk Fluid Level Report 6 - 2 9 - 8 8 Casing 3Q-09 Kuparuk Fluid Level Report 6-29-88 Casing Receipt Acknowledged: Alaska 0il & Gas Cons. Commission Anchorage ........................... Date: ............ DISTRIBUTION: D & M State of Alaska Chevron Unocal SAPC Mobil ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal ~ 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-4 Dual-Zone PBU 'A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A"Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure Buildup Test 7-6-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87' 3M-! Static Well Pressure Report 7-13-87' 3M-2. Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 IY-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 Receipt Acknowledged: AUG1 3 1987 Alaska 0il & Gas Cons. Commission Anchorage Date: DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-66 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20948 4. Location of well at surface 9. Unit or Lease Name 211' FNL, 1973' FWL, Sec. 1, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1277' FSL, 1616' FEL, Sec.36, TI2N, R9E, UM 1Y-4 At Total Depth ~11. Field and Pool 1502' FSL, 1332' FEL, Sec.36, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 102'I ADL 25641 ALK 2572 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/02/83 05/09/83 05/23/83*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+I-VD)! 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7420'MD, 6535'TVD 7296'MD, 6434'TVD YES)(] NO []I 1821 feetMD 1350' (approx.) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP, Sonic, CBL/VDL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.8# H-40 Surf 78' 24" 271 sx AS II 10-3/4" 45.5# K-55 Surf 2254' 13-1/2" 900 sx Fondu & 250 sx PI C 7" 26.0# J-55 Surf 7394' 8-1/2" 950 sx Class G & 250 sx PFC 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7047' 6658'. RRgb,' ~ 7(llq. 6797'-6857'MD 6028'-6076'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6908'-6939'MD 6118'-6143'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7122'-7142'MD 6292'-6308'TVD 7158'-7178'MD 6322'-6338'TVD N/A Perforated w/12 spf 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA B[~ief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. one RECEIVED i 51987 *NOTE: Workover performed 03/14/87. ~faS[<a 0il& ~s C,n~,~. C0mrnis~i0n Anchora~te STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CG,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIEI~2:39:DANI 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand - ., GEOLOGIC MARKERS MEAS. DEPTH 6794' 6939' 7099' 7252' TRUE VERT. DEPTH 6025' 6143' 6274' 6399' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~/~'/, (~ij*[~.?)/,.~-/ ~'.'~~ Title Associate En§ineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation- Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. : Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ..... ALAS,,.~ OIL AND GAS CONSERVATION COM, ,;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate © Plugging [] Perforate ~ Pull tubing Alter Casing [] Other ~Z] . W0RKOVER 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 211' FNL, 1973' FWL, Sec. 1, T11N, RgE, UN At top of productive interval 1277' FSL, 1616' FEL, Sec.36, T12N, R9E, UN At effective depth 1458' FSL, 1389' FEL, Sec.36, T12N, R9E, UM At total depth 1502' FSL~ 1332' FEL~ 5ec.36~ T12N~ RgE~ UN 11. Present well condition summary Total depth: measured 7420'MD true vertical 6535 'TVD Effective depth: measured 7296'MD true vertical 6434'TVD Casing Length Size Conductor 78' 16" Surface 2254' 10-3/4" Production 7394' 7" - 5. Datum elevation (DF or KB) RKB 102' 6. Unit or Property name Kuparuk River Unit 7. Well number 1Y-4 8. Approval number , 7-17'~ 9. APl number 50-- n?c)-?o~)z~R 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) None feet Cemented Measured depth 271 sx AS I I 78'MD 900 sx Fondu & 2254'MD 250 sx PFC 950 sx Class G 7394'MD 250 sx PFC True Vertical depth 78 'TVD 2254 'TVD 6514 ' TVD Perforation depth: measured 6797'-6857' 6908'-6939' 7122'-7142' 7158'-7178' true vertical 6028'-6076', 6118'-6143', 6292'-6308', 6322'-6338' Tubing (size, grade and measured depth) 3-1/2", J-55 tbg w/tail @ 7047' Packers and SSSV (type and measured depth) HRP-1-SP pkrs @ 6658' & 6894', FB-1 pkr @ 7019' , TRDP-1A-ENC SSSV ~ 1821' RFCEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure . Alaska 0il & Gas Cons, Commission Anchor3ge 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well Hi story~ Daily Report of Well Operations ~ ' Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ c~--~,~ ~-"- ~;~? Signed ¢ Form 10-404 Rev. 12 TitleAssoci ate Engineer Date 5-..~1-~ Submit in Duplicate (Dani) 5W02/16 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel3ort" on the first Wednesday afie~ a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borough North Slope Borough Lease or Unit ADL 25641 T t e Recompletion State Field Alaska Kuparuk River Alaska IWell no. 1Y-4 Auth. or W.O. no. AFE AK2343 Nordic # 1 Operator ARCO Alaska, Inc. API 50-029-20948 ARCO W.I. Pr or status 56.24% if a W.O. Spudded or W.O. begun Workover IDate 3/7/87 IH°ur Date and depth as of 8:00 a.m. 3/07/87 thru 3/09/87 3/10/87 3/11/87 3/12/87 3/13/87 Complete record for each day reported 0430 hrs. 7" @ 7394' 7296' PBTD, Chg out colrs 9.4 ppg NaC1 BPV junk on top of SSSV. RU W/O. RIH w/magnet, POOH; no rec'y. Rn 2.75" impression block, att to get impression, SSSV opened & junk feel past SSSV. RIH to 6652' w/Impression block, POOH, impression block scarred. RIH w/blind box & spanger jars, wrk junk dn hole f/6652'-6716' WLM, POOH, RD Otis. Accept ri~ @ 0430 hrs, 3/7/87. RU to kill well. RIH & perf 6709'& 6708' bet pkr & "D" nipple, RD DA. Circ well w/9.0 ppg, 9.2 ppg & 9.4 ppg brine. (Total fluid loss = 181 bbls). Well losing fluid. Pmp 2 LiteSal pills. ND tree, NU BOPE; well kicked. SI well. Circ dn tbg & hesitate pmp 48 bbls LiteSal pill into formation. Well dead. NU & tst BOPE. Pull tbg hgr. POOH w/3½" tbg. 7" @ 7394' 7296' PBTD, POOH w/3½" DP 9.4 ppg NaC1 POOH & chg out colrs on tbg. RIH w/FTA, wrk over pkr, free, CBU, POOH w/HRP-1-SP pkr. 7" @ 7394' 7296' PBTD, NU tbg spool AiasKa 0ii & Gag C0rl$. Commission 9.4 ppg NaC1 ~i~b0r~ge POOH, LD pkr & fsh'g tls. PU BP, RIH & set @ 6670', tst cs · BP to 2000 psi, POOH. ND BOPE. Kill 10-3/4" x 7" ann. ND 3M tbg spool, NU 5M tbg spool. 7" @ 7394' 7296' PBTD, Displ to cln brine 9.4 ppg NaC1 NU tbg head, tst packoff to 3000 psi. Pmp 90 bbls diesel in 10-3/4" x 7" ann. NU & tst BOPE. Tst 7" csg to 3500 psi; OK. RIH w/retrv'g tl, pull BP, POH. RIH w/bit & csg scrprs, tag fill @ 7060', drl & CO fill to 7307', CBU. Circ cln brine in hole. 7" @ 7394' 7296' PBTD, RIH w/compl assy 9.4 ppg NaC1 Fin circ cln 9.4 ppg brine, POH, LD DP. RU DA, make GR/JB rn to 7225', POH. RIH w/FB-1 pkr, set @ 7011'(WLM), POH, RD DA. RIH w/3½" CA. The above is correct Sign atu~~,~,~ ~ For form I~ep'aration and distri-bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" term may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field JLease or Unit Kuparuk River I ADL 25641 Auth. or W.O. no. ~Title AFE AK2343 I Recompletion Nordic 1 Operator ARCO Alaska, Inc. cost center code Alaska IWell no. 1Y-4 A.R.Co. Date Spudded or W.O. begun Complete record for each day reported Workover Date and depth as of 8:00 a.m. 3/14/87 thru 3/16/87 API 50-029-20948 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well JHour J Prior status if a W.O, 3/7/87 ! 0430 hrs. I pkr @ 6658' & 6894', FB-1Pkr @ 7019', TT @ 7047'. to 2500 psi. ND BOPE, NU & tst tree to 5000 psi. w/230 bbls diesel. RR @ 0200 hrs, 3/14/87. 7" @ 7394' 7019' FB-1Pkr, RR 6.8 ppg diesel Rn 207 jts, 3½", 9.2 BTC AB-Mod tbg w/SSSV @ 1821', HRP-i-SP Tst pkr/ann Displ well Old TD Released rig 0200 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing INew TD Date 3/14/87 PB Depth Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date Corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor STATE OF ALASKA ALAS~,.~ OIL AND GAS CONSERVATION COMN,,&SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown C' Re-enter suspended well ~ Alter casing D Time extension [] Change approved program D Plugging [] Stimulate ~ Pull tubing J~ Amend order ~ Perforate ~ Other 2. NaAr~:~f Operator ATaska, Inc 3'A~[eSOs. Box 100360 Anchorage, AK 99510-0360 4. Location 211' of well at surface FNL,. 1973' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1616' FEL, Sec.36, T12N, R9E, UM At effective depth 1458' FSL, 1389' FEL, Sec.36, T12N, R9E, At total depth 1502' FSL, 1332' FEL, Sec.36, T12N~ R9E~ 11. Present well condition summary Total depth: measured true vertical 7420 ' MD feet 6535 ' TVD feet UM UM 5. Datum elevation (DF or KB) RKB 102' feet 6. Unit or Property name Kuparuk R~ver Unit 7. Well number 1Y-4 8. Permit number 83 -66 9. APl number 50m 029-20948 10. Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7296 ' TVD feet true vertical feet 6434 ' TVD Casing Length Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 78 ' 1 6" Surface 2254 ' 1 0-3/4" Producti on 7394' 7" 271 sx AS I I 78'MD 78'TVD 900 sx Fondu & 2254'MD 2254'TVD 250 sx Permafrost 'C' 950 sx Class G 7394'MD 6514'TVD 250 sx Permafrost 'C' Perforation depth: measured 6797'-6857', 6908'-6939', 7122'-7142' , 7158'-7178' true vertical 6028'-6076', 6118'-6143', 6292'-6308', 6322'-6338' 3-1/2" J-55 6721 'MD , , Tubing (size, grade and measured depth) CAMCO HRP-1-SP pkr ~ 6700'MD, CAMCO TRDP SSSV (~ 1910 Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal 13. Estimated date for commencing operation March 3, 1987 14. If proposal was verbally approved · Name of approver Detailed operations program [] BOP sketch 0il & Gas 00ns. C0m~,~pproved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associate Engineer Conditions of approval Approved by Commission Use Only (JLQ) SA2/013 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I ~ ..... /-d / byorderof ~~ ~, ~1~ ~ ~~issioner the comm,ss,on Date~-~ MD Form 10-403 Rev 12-1-85 Submit in triplicatu Kuparuk Well 1Y-4 Conversion to Selective Single Preliminary Procedure 1. RU wireline. Obtain BflP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. Shear out of SBR. POOH and stand tubing in derrick. Install A/B modified couplings. 5. Pick up 3%" drill pipe and retrieve the packer. POOH. 6. RIH and set retrievable bridge plug. Install 5000 psi wellhead and test casing. Retrieve bridge plug. 7. Run GR/JB to PBTD. RIM and set permanent packer between "A" and "C" Sands. 8. Run 3~" single selective completion assembly. ., 9. ND BOPE. NU tree and test. 10. Displace well to diesel by reverse circulation. 11. Test annulus and tubing to 2500 psi. 12. Secure well and release rig. Anticipated Bottom Hole Pressure: 3000 psi Completion Fluid~ 10.0 ppg NaCi/NaBr Brine YPAD/iY-4a /ih ANNULAR PREVENTER § PIPE RAPIS 4 BLIND RAILS 5 TUBII~ HEAl) 1. 16' CONDUCTOR SWAGED TO 9-5/8' 2. 11'-3000 PSi STARTING HEAD 3. 11'-3000 PSI X 7-1/16'-5000 PSI TUB)NG HEAD 4. 7-1 / 16' - 5000 PSI PIPE RAHS S. 7- t / 16"- SO00 PSI BLIND RAMS 6. 7-1/16" - 5000 PS1 ANNULAR ACCUMULATOR CAPACITY ,TEST 1. CHECK AND FILL ACCUI"IULATOR RESERVOIR TO PROPER LEVEL WITH HYDI:b~ULIC FLUID. :2. ASSURE THAT ACCUHULATC~ PRESSUI::~ IS 3000 PSI WITH 1SO0 PSI DOWNST'REAI'I OF THE RE(~JLATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SII"IULTA~SLY AND RECORD THE TII'IE AND PRESSURE REHAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUt'lla OFF. 4. RECORD ON THE IAD, C REPORT. TI~ ACCEPTABLE LOWER LIT'lIT I$ 4,5 $ECONOS CLOSING TiI"E AND 1200 IiSI REI'IAINING PRESSURE F E~ 2 6 BOP STACK T;ST Alaska Oil & Gas Cons. 1. FILL B~ STACK A~ MANIF~D Wl~ ARC~C DIE~. 2. CHECK ~AT ALL H~D~~ 5C=~ A~ FULLY ~AC~D. PREDE~I~ D~ ~AT ~5T PL~ WILL ~AT A~ SEAT IN ~LLHEAD. RUN IN L~K~N ~~ IN ~. 5. CLUE A~AR P~VEN~R AND C~E$ A~ ~YPAS$ ~ ~E ~ANIF~D. 4. TEST ALL C~P~NTS T0 250 PS1 A~ ~O F~ 10 S. I~REASE P~S$~ TO 1800 PSI ~0 ~O F~ I0 HI~S. BLEED T0 ~ PSI. 6. ~EN A~LAR P~VENTER A~ CLUE PIPE ~US. 7. INCREASE PRESSU~ TO 3000 PSI A~ ~D F~ 10 8. CLUE VALVES 01RECTLY UPSTREAU ~ CH~ES. BLEED 0~STPEAU PRESSU~ TO ~RO PSI TO TEST VALVES. ~ST ~AINI~ UANIF~O VALVES. IF ANY, ~J~ ~0 PSI UPS~E~ ~ VALVE WI~ ~RO PSi 0~STREAU. 8LEE0 SVSTE~ TO ~RO PSI. 9. ~EN PIPE ~A~S. e*C~F ~UNNI~ dOINT AN0 PULL ~T ~ H~E. CLUE ~LIND aAUS AND TEST r0 ~000 PSI F~ 10 ~INU~S. BLEED TO ~RO 10. ~EN ~LIND RA~S AND RECOVER TEST PLUG. ~AKE SURE UANIF~D LINE5 APE FULL ~ ARCTIC 01ESEL ~ ALL VALVES ARE 5ET IN ~E 0RILLING P~ITI~. I 1 . TEST STANDPIPE VALVES T0 ~000 PSI. 12. T~ST KELLY C~K5 AN0 INSt0E B~ T0 ~000 PSI WI~ K~EY PUUP I~. REC0PD TEST INF~UATI~ ~ BL~T PREVEN~R rEST ~u. AND SENO TO DRILLING SUPERVISe. I~. PEPF~ C~PLETE BOPE TEST ONCE A ~EK AND FUNCTI~ALLY OPERATE B~E DAILY. .. J0 JULY 28, 1986 F£BRU~"t' 19, 1986 7/6/83 lA-4 10/29/83 lA-5 2/8/82 lA-7 517182 1~-9 1/25/82 3/23/83 1/19/83 lA-11 3/21/83 31818Z lA-12 4/1/82 lA-14 615182 lA-15 5/11/82 1A-16A 6/8/82 lC-1 1C-Z 1C-3 1C-A 1C-5 1C-6 1C-7 1C-8 ' -. lB-1 18-2 18-3 18-6 15-7 18-8 18-9 ~ ID 1D-1 5/9/81. 518181 7/13/81 319181 2126181 :--11/30/81 5/19/81 5/Z1/81 lZ/26/81 6125181 11/16-18/81 311ZlBZ 11123181 12/28/81 814182 1D-3 1D-~ 1D-5 1D-6 5/Z3/83 815180 7/30/80 8113180 6111/81 6/9/81 6/8/81 5110178 Oil & Gas Co,,s ........ Attachment Page 2 Drill Site 1H Drill Site lQ Well No. Log Date~ 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Well No. Log Date~ _ Drill Site Well No. L~og Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-2B 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10128/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Dri 11 Si te 1G Well No. L]g Date -- 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 Drill Site 1F Well No. 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 1F-7 . Alaska Oil & Gas C~ns. Ar~or~e ~Log Date~ 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment _ Page 3 Drill Site 1¥ Wel 1 No. Lo9 Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~ 6 / 18 / 83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1.Y-9 6/20/83 -~Y~l~ 5/10/83 ~ 11/21/83 ~7/~.8~/8~ 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site 2Z ' ' Well No. Lo9 Date tZZ~ l/1 o/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF: pg-O052 Anchorage Page 3 Drill Site 1¥ Well No. _Log Date .~0/21/83/ '1Y-2 6/10/83:-~ %3/4/84/x --' 1¥-3 "6/18/83 '1Y-4 '~ 7/2/83 ~1Y-5 "~6/29/83 , 'qY-6 ~6/27/83 Y-8 x6/22/83 ~ 1Y-9- ~/20/83 * ~1Y-11 ~5/10/83~ 1Y-12 ~5/25/83 ~ 1Y-13 ~5/27/83 ~1Y-14 ~/13/83~ ~5/18/83/ ~1Y-15 ' ~/29/83 ~ 1Y-16 ~'5/30/83' ~ ~10/23/83 ~ Drill Site Well No. Log Date 2Z "2Z-1 ~2Z-2 .~ "~z-3 "~2Z-4 ~2Z-6 '~2Z-8 7/10/83 6/24/83',,,. 7/19/83./ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site 2C Wel 1 No. --- 2C-4 '~/~ 2C-7 Log Date ~2/19/85 \ ~ 2/28/85/' ~1o/15/84 .! VLF:pg:O029 RECEIVED FEB ~ 1 1985 AJaska 011 & Gas Coos. Comml~lorl /~chorage ARCO Alaska, Inc/ Post Office .,x 100360 AnchOrage, Alaska 99510-0360 Telephone 907 276 1215 F"..' IE T [..I F,.' N 'T' 0 ' 'T' F.'. A N ,F H I T 'i° E D R ECr:.-'. I F'T AND l-! L.'..i F;,' E.-Z [.J I '¥' I--I A I-"< r.-..l T I..I E F:' 0 I... I....r.;i[4 Z i',{ G. F,'IE'¥ U R N () N E= .:7 ]: (.i- N E g CCI F' Y [) F 5; !'=': E! U E N C I=' O I= E V E N T S · ~ ~' F 1... U I D T. D i ET-'i 6 PL.IHI=' GI-.ZLI._ED i A .... 8 F'BU 2(; ..... i6 FL. LJ];D ]:D 2 C'.-- 9 :?'T'AT :[ C BI--1F' ", T:..' .- 2 F' B [.J ..:.' .... ..... · .-. '- ..,' ('; ,/I_ ~URVEY 2.f}--~ FLOkJ I N6 '..rs:HF' L:JATIE F~ BATCH · ..r. T I!!; H .?., F:' I....r....l A ,fi.' .Er-:..' A C I'-,' N C) I;.J I... I'": D TH .'I,; :';' '¥F-:AN~H I. TTr-t',l .... 4 / '2 /:,° ~:'.) , · ,~ r) 1:-7 ,.*- / t .~,/,::, .., 4/6-T'/8'-~ 4/618'.5 4/6/8% F,'..'ECE]: 1::'-¥ ACi-'..' ,'."~.C)klLEDGEI) · i'~.r-:: I I I INC !J r-, ^ .,-,, ~ r-,--, l..,. d (] H N,]-'. 'f' C~ N EXXON h'iri.[:-:''r~ F'H]:I I .T.F'~ fl.T.L N."ZK CLEF..'K J, R-'A.-~']'F, hEI_L'~ A~OO Alaska, Inc. i~ a Subsidiaqf o! Aflanli~l~.ichfieldgompany ARCO Alaska, Inc.' · Post Office L .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 F:.i EZ'T' U F.: N 'T.' 0 · ARC:[) AI...A,?;I".'.A: !NC., ATTN: REC. ORi),S; CL. EF:.~I< A'T (]--- i i f '.:.."- B F' ~ 0 ,. B !Ti X i ,::) 0 ..-!!: 6 () AHCH[DF-'.:AE.E], Al< ?'"?.S:i 2 [)1'"' · I .I [."..: F;.: IT. I,.J ]: i" H AIRI!..E TI-.IIE F'OL.I...OHIi',!G 'J:'T'I!i:HS., ,r.:'!...r..~A,s'.r:L' ACI<N[)WI...IEI)[~IE F..'I:ETUF..'N !_-ii--.]!!-- ,:?IC.,.NIE)} CCIF'Y ('JF-' T!--!]:,? 'TI.:.'.AN,"]H:[T"I'~'~'~I ..... ;"] ~::' f:) U E N C' 1:' [) Iz '..- '"' · ........ ~_. V r.E N 'T' ~-~ F..' Ii:_' C .r. T I::' T "' .... " E n · .... h'L-r--. !'~ 0 bit_ E D d .,... :(.:: F' A.r:E B., C: U R,r':: :[ !'Z i'".: : C:HEVROF.! .... ,_':.-. H .................. : l Pfi : FjTi i::i :'; ................... T', r;: .i: L. !... I N C-. !J """ '"' .... ........ I'- ~-I ,:~ r'; 1::, r-;,' ! ...... ,I (-'-'- H i! :-'7 'F 0 i'~ EXXON Hr',c,'r~ F'I--!]]! IIPS FI]'L. I . '_> .~.~ .I. L ............... i':~;~K ,'.']:LEF-'.i-'-.'. ,J, R(~THHr.-~I...L ARCO Alaska, In¢. is ~ Subsidiary of All~nticR. ichtieldComp~ny RECEIVED ,4laska Oil & Gas C, ons. {,~ ....._ ....................... ::.....~:?:::~ "~ ...... :'.:':~ion ~1::' /"' "'~ ri U i'--] ]: .r.) N K., T t~L.. I N,/V ~'.5 U !... T . , KUPAJ:L]< D',O I NEERI NS TO:. William VanAlen ~: D.W. Bose/Shelby J. Mat_~hews. Transmitted herewith are the followin9' PLEASE I~)TE· BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, ~ ALASKA, INC. AT'FN: SHELBY J. MATTHB~ - ATE)/111 5-B P. O. DOX 100360 Ah,O-DP, AGE, AK. 99510 KUPAI~K BA31NEER! bE; TO: DATE: WilliamVa~Aien ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the foll~i~. PLEASE KEFFE~ F- FILM, T- TAPE, PC- PHO~PY A~aska Oii & Gas Cons. Commission ARC0 ALASKA, I NE:. Anchorage A'I'TN: SHELBY J. ~4AI-iTIE~ - ATO/1115-B P. O. BOX 100360 ANCHORAGE, At(,. 99510 ARCO Al'aska, Inc. Post Office B~)~X 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton- Enclosed are completion reports and gyroscopic surveys for the following wells' 1Y-4 2Z-7 2Z-8 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GRU3L56' sm Enclosures RECEIVED J U L '- 0il & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany , ¢'¢- STATE OF ALASKA ----~ ALASK/-, ..AL AND GAS CONSERVATION C .~-MISSION WELL COMPLETION OR RECOMPLETION REI ORT ANI LOC 1. Status of Well Classification of Service Well OIL~[~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-66 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20948 4. Location of well at surface 9. Unit or Lease Name 211' FNL, 1973' FWL, Sec. 1, TllN RgE, UM ] --[ Kuparuk River Unit ' LOCATIONS At Top Producing Interval VERIFIED / 10. Well Number 1277' FSL, 1616' FEL, Sec. 36, T12N, R9E, UM ~ Surf. F:~___~I 1Y-4 At Total Depth B.H. __[~ I i 1. Field and Pool 1502' FSL, 1332' FEL, Sec. 36, T12N, R9E, UM ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 102' RKBIADL 25641 ALK 2572 12. Date. Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1 5. Water Depth, if offshore 16. No. of Completions 05/02/83 05/09/83 05/23/83 N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7420'MD,6535'TVD 7296'MD,6434'TVD YES ~] NO []I 1909 feet MD 1350' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP, Sonic, CBL/VDL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.8# H-40 Surf 78' 24" 271 sx AS II 10-3/4" 45.5# K-55 Surf 2254' 13-1/2" 900 sx Fondu & 250 sx Pe'rnafrost C 7" 26.0# J-55 Surf 7394' 8-1/2" 950 sx Class G & 250 sx 'ermafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7158 ' -7178' 3-1/2" 6721 ' 6700 ' 7122'-7142' 6919'-6939' w/1 2 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6908'-6919' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6797 ' -6857 ' N/A 27, N/A PRODUCTION TEST Date First Production 1 Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ 'FIowTubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U L ] 1983 Alaska Oil & Gas Cons. Commission Form 10-407 ~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . ~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6794' 6025' N/A Base Upper Sand 6939' 6143' Top Lower Sand 7099' 6274' Base Lower Sand 7252' 6399' 31. LIST OF ATTACHMENTS Drilling History, Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevatiOn is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ..... AR,GO, ALASKA, I NC. PAD 1Y,~ WELL NO: 4 SIGMA-OYRO ,JOB NO: AO583Z0142 KUPARUK FIELD~ NORTH SLOPE, ALASKA E;I G=GYRO, ..... 0=7~,0,, SIGMA 300 GYRO NO: 746, PROBE NC,: 067 , FORESIGHT: ~!WEST !~'~ A P~.:.I'R(-)LANt:: C'()^4f:¢INt RECORD OD--~:URV. EY .................................................................................................... ,; RADIUS OF CURVATURE METHOD ARCO ALASKA, INC. COMPUTATION PAGE NO. ' ',.o PAD 1Y,, WEL,L NO: 4 S.'IGMA-GYRO ,...IOB-.NO: A0583Z014,2 ~ ........................................... TIME .................. DATE K JPARUK F I ELD, NORTH SLOPE ALASKA 12: 00: 36 14-dUN-83 TRUE ~ , ~' J ~ MEA.:.LRED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N 8 U L A R C: L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D ........... M D M EEE.T EEE,T EEET EEE.T ............................................. ~EEI.,.-- ............................... EEEI D .......... ~ .............. DGLIOOFT 3000. 12 19 N 35 13 E 100. 2996.27 56.78 2894.27 34.71N 44.93 E 56.78 N 52 19 E 2.03 3100. .......... 13,..,.18-,,N.-35..,2.1..,E ................ 1.00. 30~3.J8 ........................ ~,7,...98 ........ 2~1..~8: ..................... 52,..81,,-.N 57.,75,--.E ............... ~8,..25 ........ N_,4~...,,331,.E 0..9~ 3200. 15 47 N 36 38 E 100. 3190.57 102.07 3088.57 73.13 N 72.51E 102.98 N 44 45 E 2.5C) 3300. 18 8 N 37 59 E 100. 3286..21 130.24 3184~21 96.33 N 90.19 E 131.96 N 43 7 E 2.38 3400. 20..47..,N.39-43, E ............ 100. 3380...~8 3500., 23 5 N 40 31 E 100. 3473.24 199.15 3371,24 150.85 N 135.18 E 202.~..~, 3600. 2~ 4,,.N,,-,41 O.,.,E ......... ?.100. ......... 35&,4.,,53' ................ 239b..10 ............ 34~2,.-53 ............. 18.1..7.4..,..N ...... 1~.1...81-.E ......... 2,43..3A ........ N.,.,~I ....... 4.1.,.,,E 370C). 27 5 N 41 48 E 100. 3654.35 282.25 3552.35 214.71 N 19C).88 E 287.29 N 41 38 E 2.C)4 .~.:,,.c'~'op~ 29 36 N 42 6 E 100. 3742.35 328.94 3640.35 ~= . ._ · ~...0.01 N 222.62 E 334 76 N 41 41 E 2 ........ ~.. C. ~ 1 ~ ~ N 4= ~ E t ( 0.-- ~ 8~,~ .-~,9-- - ~.,7 ~. ~7. -- ~6.. ~ .......... Z87. ~2.-N ............. ~7..OZ-.-,E ...... ~85...~,~- N....41.--,.46-~ .................. 4000. 34 24 N 43 24 E . 4100., .......36 ....... 8.-.N..-45...22 E 4200. 38 42'N 47 14 E 4300. 41 37 N 48 16 E 4400.. 44.38 N 49 51E 10 ~91.7.. Oi:j ,.,, ,,,~,~.~,~,~,.~,~,,,~ 3~7.84 N ~'~4.27 E 440 54 N 4 ~ ~ E 2 ._..~ 399.~." , ",~,~" ~ ~ , t'~ ~5 ' ~,:"',~ '"~ ?,"~,',~4.~7 E ' ~.6Q E 558.86 N 42 39 E 2.80 ' ~' ~"" ,~: ~r"34 E 623.13 N 43 10 E 3 00 ;~.~1 ..... 4.JC0 46 35 N 50 36 E 100. 4292.36' 754.76 4190.36 544.95 N 532.93 E 762.22 N 44 22 E 2.C)2 4600. .4~ 17 N..50 .37,.E ............ 100, 4361,27 ...........827, 20 ......... 425~.-27 ............. 590..93....N 588...95-E ............... 834,3.0 .......N44.-54,.E ........... 0.31 4700. 46 7 N 50 29 E 100. 4430.47 899.35 4328.47 636.79 N 644.69 E 906.16 N 45 21 E O. 4800. 45 56 N 50 44 E 100. 44~9.90 971.29 4397.90 682.47 N 700.31 E 977.8~ N 45 '44 E 0.26 4900.. ..... 4~.--~O-N-~0,-,48--E - ~ 100. ..... 4~&~..-~0 ...... 5000. 45 25 N 50 54 E 100. 4639.43 1114.52 4537.43 772. 5100, 44 49,,N ~0, 59 E ............ 100. .......... 4709.98 .... 1.18~. 86 4&07.,~8 ....... 817..64.-~N ..... 8~&.. 4,1--,-E ....... 1.-1-9.1-.-.C~1 .... N.4&-40~ E .... 0.60 · 5200. 44 18 N 51 0 E 100. 4781.22 1255.52 4679.22 861.80 N 920.95 E 1261.29 N 46 54 E O. 52 5300. 43 49 N 51 14 E 100. 4853.08 1325.05 4751.08 90q.45 N 975.09 E 1330.66 N 47 7 E 0.51 5400. 4:3 2~ N ,51 6 E ..... 100,. 5500. 42 33 N 51 2 E 100. 4998.61 1462.20 4896.61 991.56 N 1081.89 E 1467.54 N 47 3C) E 0.86 · 5600 .. 41-22 --.N--. 50 59. E .... 100. .... 5072. -95 ~-1529.,0E, .... 4970.~5 ...... 1.033.63--N .... 1-133.87--E---1534.-~.-Sl ~N-47--3~-E ........ 1 .... 1S~ 5700. 40 6 N 50 38 E 100. 5148.72 1594.30 5046.72 1074.87 N 1184.46 E 1599.46. N 47 47 E 1.29 58(:)0. :39 25 N 50 31 E 100. 5225.59 1658.23 5123.59 111.5.48 N 123:3. :38 E 1663. :35 N 47 53 E O. 69 · 5900.. 38 .~7 N 50 4/~ E 100.--. ~303.09 . 1721.89-- ~201.-09 ..... ll~5~.D4.-N .... 1282..-74-E ...... -1--72~.-.4-7- .... N-,47--.~9...E 0.48 ,, f, ,. ARC:O ALASKA, INC:. COMPUTATION PAGE NO· 1 'PAD 1Y, WELL'"-NO: ....... 4 S,t-GMA-GYRO dOB-NO~ AO583-Z0143 T,.t,ME .DATE ~ ....... KLIPARI'JK FIELD, NORTH SLOPE, ALASKA 12: 00:36 14-dUN-83 ' TRUE MEASURED DRIFT, DRIFT COLIRSE VERTICAL VERTICAL SUBSEA R E C T A N G U I A R E: L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY ~ FEET ..... D M .........:.D ..... M ................ FEE.~ FEET ..................... FEE~ .............................. FEET ........................................................ FEET ......................................................... FEET~ .................................. D ............ M .................. DG/i. OOFT O. 100, 200. 300. 400· 0 0 0 O. 0.00 0.00 -102.00, 0.00 0.00 0.00 0 0 0.00 7 N 89 54 E 100. 300.00 -0.22 198.00 0.53 S 0.13,E 0.55 S 13 45 E 0.09 500. 0 ~' . . . . 1.13 E 1.24 $ 66 11 E O, . /,o N 82 5 E 100. 500 00 0 59 3.g8 O0 0.50 700. 0 34 S 74 38 E 100. 6,~.9~ 2,02 5~7.9~ 0.62 S 3.03 E 3.09 S 78 24 E 0.12 800. 0 37 S 71 1 E 100. 799.9:3 2.63 697.98 0.93 900, 0'' 44",- 7'~' ','22' .'E 100 ~ ................ 899,~,,,97 ....................... 3.'3~ ............. 797.,-97 ........................... 1.24..-,~ .......................... 1.-9.--E ................ ~-.. ~3 ..... ~',,.-71-~-.-.-~ E O.-16 1000. 0 46 S 78 48 E 1100... 0-31..S 62 I E 1200. 0 18 S 55 7 E' 1300. 0 8 S 4 14 W 1400.''" 0 6'S 3.38 W 1500. 0 16 1600. 026 1700. 0 36 1800. 0 41 1900., ....... 0.25. 2000. 0 18 2100. 029 2200. 0 12 2300. 0 21 2400., 0 30 2500. 2 44 2600... -2 48 2700. 3 43 2800. 5 54 2900.. .... 10-17 10 999.9 1099. 1 1199. 1299.95 1.49 6.51E .58 E .21E :.37 E .36 E At:~':'THC)tANEC?I)Mi:~NY S 61 47 W 100. 1499.95 4.59 13~7.95 3.10 S 8. S 43 38. W ...... 100. 1~99.9~ ....... 3.96 .... 1497.9~ ......... 3,48..$ .............7. E; 27 40 W 100. 16~9.95 3.09 1597.~5 4.22 S 7. S 18 2 W 100. 17~.~4 2.10 1697.~4 5.27 $ 46 36 E 100. 1999.93 1.29 1897.93 6.81S 6. S-76 7..E ......... 100, ..... 20~9.93 ................. 1.57 ..... 1997..-~3 .................. 7.15..$ ................ 7. N 67 7 E 100. 2199.93 2.07 2097.93 7.10 S 8. S 76 16 E 100. 2299.93 2.48 2197.~3 7.06 S 8. N84 17. E .... 100.. 23~9..~3 ............. 3.-04 .... 2297.~3 ...............7.1-1...-S ............. 9. N 7:5 34 E 100. 2499.88 5.76 2397.88. 5.74 S 11. N-45.-.42. E .-t00.. 2599..76 ......... 10...49 .... 2497..-76 ........ 2.07--.S ............ 14. N 55 10 E 100. 2699.60 16,18 25~7.60 1.55 N 19. N 37 13 E 100. 27~9.24 24.50 2697.24 7.34 N 25. N 35 19. E ..... 100.- ...... 28~8.22 ......... 38.04 ...... 279&.~2~ ......... 18.~0--N ....... 33. · . 6.68 S 77 6 E 0.03 8.51 S 74 38 E 0.23 8.77 S 72.43 E 0.27 8,..8~ ........ $---7t ...... 1.9.,E 0.03 18 E 8.75 S 69 15 E 0.23 68, .E ....................... 8.43 ...... S .6._=-, ...38- E ....0..21 15 E 8.30 S 59 26 E 0.21 71 E 8.53 S 51 53 E 0.14 87 E 9.68 S 45 15 E 0.2~ 48,-E ......... 1.0...35 08 E 10.76 57 E 11.10 S 50 31 E 0.23 32~-E ......... 11-.-73--~-52--39- -E 70 E 13.03 S 63 53 E 2.43 84-E ........... 14-.. ~.9--.$-~ 82 ...... 3-E ..... O. 4'B-,, 23 E 19.30 N 85 23 E 1.06 27 E 26.32 N 7:3 48 E 2.63 ARCO ALARKA, I NC. COMPUTATI ON PAGE NO. .:,~' PAD 1.¥, ........ WEL~L:,,~' NO~ ...... 4 SIGMA-GYRO ,:.iOB.~.NO: ...... AOS83Z014.,2 TIME ....................... DATE- ' I ' '-M I "*~ ' k...t PARUK F I ELD, NORTH SLOPE, ALASKA 12: O0: ._'~ :, 14-,J1_ N-o._, MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R'E C: T A N G U L A R C: L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION L:;EVERITY FEET £1 M D ..... M FEET FEET FEET , FEET FEET FEET' 6C)¢)0. :37 50 N 50 33 E 100. 5381.46 1783.48 5279.46 1194.'.~1 N 1330.80 E 1788.53 N 48 ~ E 1.12 - 6100~ ........ :37 2 'N50 ~"17'"'E t00, ......... 546 (~'~i' 85 1844~"24 .......... 5358.85 12C'{C'~'64"N ......... 1'C'~7~','66'-'E ............. 1849~"2'7 N"'48 6200. ~ 5;~40 ~3 1904 24 5438 83 1271 ~= ~ ~ · _b 44 N 50 38 E 100. = ..... ~.J N 1423.96 E 1~0~.25 N 48 14 E 0.36 ~' . c.6~1.26 1963.63 5519.2~ 1309 38 N 1470.02 E 1°~' 6~00. 36 10 N 51 0 E 100 = ~ . ;.~.c..bl N 48 18 E 0.61 . . . N 48 27 E I ) 6~,=¢]0. ~,4 ~;1 N 50 31 E 100 5783 88 2080 00 5681.88 1383.04 N 1560.16 E 2084. 6~00. :~4',.,.42",N, E ................ 100.,~ 58/.-&~.t0 .'~ ........ 21,,36 ,,,91 ......... ~7&4~,..,10 .......... t419..~. 1 N t&04, 2.1,-E ......... ~t4.t~,,~, 8~ 6700. 34 32 N 51 25 E 100. = ~,~48.39 217J3.71 5846.39 1454.77 N 1648.44 E 21~8.57 N 48 34 E 0.37 · ~.~ N 51 43 E 100 &030.29 2251.08 .J9~8.29 1490.42 N 1&93.39 E 2255 87 N 48 -6900. 35 "~7." N 1 .....I~'E .................. 100 ~ .............. ~1~,1.,1,.-,,.6o,=,,'~.~09,~.-2t .......... ~00~,-~.,-~, ........... 1.~,~., 64-,N ........... t.7,~48,88-E ........ -23 ~,~4.,,,.~4 10, 1 1 7000. 35 20 N 51 0 E 71C)0. 3~ ,28. N,51 .... 17 E 7200. 35 12 N 51 35 E 7250. 35 2~ N 52 25 E PRO._IECTED TO PBTD - 72.g6 MD 1784.06 E 2371.94 N 4:9 47 E C)."'¢,..-,.) .17, E 242.-'.9..82 ......... N,.,,,,48.,..,DC~.,E .................. 0,...~-"'¢) 40 E 2487.61 N 48 54 E 0.31 19 E 2516.48 N 48 5~ E 1.07 729~,. 35 2A, N 52 2~ E ..... 4&. ~434.43 2~38.~8 .... ~332.43 ...... l$&9.5§..-N .... 1918.33.-E .... 2~4~..t.1 ....... N..-.48,~8 E ......0.00 PROJECTED TO TD - 7420 MD 7420. 35'26 N 52 25 E 124. 6535.46 2610.49 6433.46 1713.40 N 1975.31 E 2614.88 N 49 4 E 0. , FINAL CLOSURE - DIRECTION: N 49 DEGS 3 MINS 41 SECS E DISTANCE: 2614.88 FEET PAD 1Y, WELL NO: 4 SIGMA-GYRO dOB NO: AO583ZO142 KUPARUK FIELD, NORTH SLOPE, ALASKA · 'E_-;I'G-OYRO, .......... O--?250,~-',"~'SURVEYOR: ..........PEFFERKORN/MILLER~ ..... DA~f'E RUN: ....... 1'"2-MAY-8"3 · =,IOMA :300 GYRO NO: 746, F'ROBE NO: 067 · FORES,IGHT: ....... "WEST" ............................................................................................................................................................................................................................................................................................................................................................................ ARCO ALASKA, INC. COMPUTATION pAGE NO. ,~ 1 PAD. 1 Y; WEL, L ..,NO: 4 s.: IGNA-GYRO dOB;.,NO: .....AO583ZO 142 TI-NE ....... DATE. KUPARLIK F I ELD, NORTH RLOPE, ALASKA 12: 01: 32 14-,JUN-83 ' =,==MARKER=,====== .......................................................... ~RUE ................................................................ SUBSEA CODE MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL NAME DEPTH DEPTH DiFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS ~EET...~ ~E.E~ EEE~ ....................... EEE~ ................................... FEE~ ................................................... EEE.T-.-- ................ D ....... ~ TOP UPPER SANDS 6794.00 6025.38 768.6 5923.38 1488.27 N 1690.71E 2252.44 N 48:39 E BASE.,.UFFER....~AN~ 6~....00 ......... 61A~.,.~.l ............. ~..,..~ 60.A. 1..,...~.1 .............. ........ ~ TOP LOWER SANDS 7099 O0 6273 78 '~ · . · ~.2 6171.78 1599.05 N 1828.74 E 2429.~..,'~= N 48 50 E BASE LOWER SANDS 7252.00 6398.59 853 4 6296 59 1653 98 N 1°0o .... ~ .... 12 E 2517.64 N 48 ~,6, E A P~/'ROI_AN[:.: · Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' - ' Op~rato~, W~i 1 Name aha Reports and Materials to be received by: Date Required Date Received Remarks · Completion Report ...... Yes Wel 1 History Yes Samples , .Core Chips Registered. Survey Plat V~ 3 Inclination Survey- /J'/d .... -" Drill St. om Test Reports Production Test Reports y 7-- C} / '-~,.~ ~"" ' -:' '"" Logs Run. Yes 1Y-4 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1645 hrs, 05/02/83. Drld 13-1/2" hole to 2280'. 'Circ & condition hole. Ran 56 jts 10-3/4" 45.5 #/ft, K-55, BTC csg w/shoe @ 2254'. Cmtd 10-3/4" csg w/900 sx Fondu & 250 sx Permafrost C. Bumped plug w/1500 psi - ok. ND 20" Hydril & diverter. NU McEvoy speed head & tst to 2000 psi. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg - ok. Drld FS & 10' new form. Tstd form to 13.3 ppg EMW - ok. Drld 8-1/2" hole to 7410'. Ran logs, Run #1, DIL/SFL/FDC/CNL/GR/SP f/7400'-2255'; Run #2 Sonic f/7400'-2255'. Cont drlg to 7420' TD as of 05/09/83. Ran 188 jts 7" 26#/ft J-55 BTC csg w/shoe @ 7394'. Cmtd 7" csg w/950 sx Class "G" cmt. Instld 7" packoff & tstd to 3000 psi - ok. ND BOP. Arctic packed 10-3/4" x 7" annulus w/250 sx Permafrost C cmt. Instld master valve. Secured well & released rig 1200 hrs, 05/10/83. HILL/DH19 06/13/83 RECEIVED J U L -- ] 1983 Alaska Oil & Gas Cons. Commission Anchorage 1Y-4 COMPLETION SUMMARY Accepted rig @ 0200 hours, 05/21/83. ND tree. NU BOPE & tstd - ok. RIH & perf'd the following intervals' 7158 - 7178 7122 - 7142 6919 - 6939 6908 - 6919 6837 - 6857 6817 - 6837 6797 - 6817 w/12 spf Ran 3-1/2" completion assy w/tail @. 6721', pkr @ 6700', & SSSV @ 1909'. Tstd hanger to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball and set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1700 hrs, 05/23/83. GRU3:CS6 JUL -- Alaska Oil & Oas Cons. Commission Anchorage / KUPARUK ENG ! NEERI hE; TRAN~,~! TFAL #~ TO: WilliamVanAlen ~: D.W. Bose/Shelby J. Matth~vs Transmitted herewith are the following- PLEASE hE~ F - F ! I_M, T - TAPE, PC - Pt-DTCEOPY - / BEC_ASE RERJRN RECEIPT TO: ARCO ALASKA, lINE:. ATTN: SHELBY J. t,~']q'HE~ - ATO/111 5-B P. O. BOX 100360 AI'~C~GE, AK. 99510 DATE: . .JUN if 0 ]~98]~ Alaska Oil & Gas Cons. Oomrnissiori Anchorage ARCO Alaska, In( . Post Office aox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton' Enclosed are subsequent sundry reports for the following wells' 1Y-4 1Y-5 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GRU3L58-sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ STATE OF ALASKA ~-' ALASK~ OIL AND GAS CONSERVATION UoMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [29X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-66 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20948 4. Location of Well Surface: 211' FNL, 1973' FWL, Sec. 1, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 102' RKB 12. I 6. Lease Designation and Serial No. ADL 25641 ALK 2572 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ND adapter flange & master valve. RU Gearhart WL unit & mast. Ran CBL/VDL/GR/CCL f/7296'-2000'. f/surface-7250'. RD Gearhart. NU adapter flange & master valve. Top 7" csg with a diesel cap. wel 1. Ran gyro Secured Accepted rig ~ 0200 hfs, 05/21/83. 7158' -7178' 7122'-7142' 6919' -6939' 6908 ' -6919 ' 6837'-6857' 6817 ' -6837 ' 6797 ' -6817 ' w/12 spf ND tree. NU BOPE & tstd - ok. RIH & perf'd the following intervals: Ran 3-1/2" completion assy w/tail @ 6721', pkr @ 6700', & SSSV @ 1909'. Tstd hanger to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig ~ 1700 hfs, 05/23/83. 14. I hereby cer~i,fy that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cu,l~, L;0mr~jss Signed ~/'~/'~ (~"~,~' Title Area Drilling Engineer AiJ0h0,a98Date '~r~~ The space~~or mission use , Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-14~0 GRU3/SN24 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Enclosed are the Monthly State Reports for the following wells' * West Sak SWPT #1 * Ciri Wolf Lake 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14. 2Z-1 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to the confidential material contained in these reports, please handle and file in a confidential manner. Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH7' sm Attachments jUN Alaska Oil & Gas Conu. Oommis~iorJ An[;hora§e STATE OF ALASKA ALASK, 'ILAND GAS CONSERVATION C '~IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ;~ Workover operation [] 2. Name of op. erator 7. Permit No. ARCO Alaska, Inc. 83-66 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20948 9. Unit or Lease Name FNL, 1973' FI~L, Sec. 1, TllN, R9E, UM Kuparuk River Unit 4. Location of Well 211' at surface 5. Elevation in feet (indicate KB, DF; etc.) PAD 66', 102' RKB 6. Lease Designation and Serial No. ADL 25641 ALK 2572 10. Well No. 1Y-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May ,19 83 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ' Spudded well 0 1645 hrs, 05/02/83. Drld 13-1/2" hole to 2280'. Ran, cmtd & tstd 10-3/4" csg. Drld 8-1/2" hole to 7410'. Ran logs. Cont. drlg to 7420' TD. Ran, cmtd & tstd 7" csg. Arctic packed the 10-3/4" x 7" annulus. Instld master valve & released rig 0 1200 hrs, 05/10/83. SEE DRILLING HISTORY 3. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe ~ 2254'. Cmtd w/900 sx Fondu & 250 sx Permafrost C. 7" 26 O#/ft, J-55, BTC csg w/shoe ~ 7394' Cmtd w/950 sx Class "G" cmt SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run Run #1 DIL/SFL/FDC/CNL/GR/SP/ f/7400'-2255'. Run #2 Sonic f/7400'-2255'. O.' DST data, perforating data, shows of H25, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE .................. DATE NOTE--Repo/°n~tl~s f~rm iSrequired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas--Conservation Commission by the 15th of the succeeding month, unless otherwise directed. H I LL/MR24 Form 10-404 Submit in duplicate 1Y-4 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1645 hrs, 05/02/83. Drld 13-1/2" hole to 2280'. Circ & condition hole. Ran 56 jts 10-3/4" 45.5 #/ft, K-55, BTC csg w/shoe @ 2254'. Cmtd 10-3/4" csg w/900 sx Fondu & 250 sx Permafrost C. Bumped plug w/1500 psi - ok. ND 20" Hydril & diverter. NU McEvoy speed head & tst to 2000 psi. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg - ok. Drld FS & 10' new form. Tstd form to 13.3 ppg EMW - ok. Drld 8-1/2" hole to 7410'. Ran logs, Run #1, DIL/SFL/FDC/CNL/GR/SP f/7400'-2255'; Run #2 Sonic f/7400'-2255'. Cont drlg to 7420' TD as of 05/09/83. Ran 188 jts 7" 26#/ft J-55 BTC csg w/shoe @ 7394'. Cmtd 7" csg w/950 sx Class "G" cmt. Instld 7" packoff & tstd to 3000 psi - ok. ND BOP. Arctic packed 10-3/4" x 7" annulus w/250 sx Permafrost C mct. Instld master valve. Secured well & released rig 1200 hrs, 05/10/83. HILL/DH19 06/13/83 AIo~-~',:, Oil ;~-~ Gas [;,~nu. 6ommission 'MEMORANDUM State of Alaska / ~ SKA OIL ~D GAS CO~SERVATION COMMISSIO~ TO: C. V~/~te~on Cha~K.~ THRU: Lonnie C. Smith Commissioner Petroleum. Insector DATE: FILE NO: TELEPHONE NO: SU BJ ECT: May 26, 1983 Witness the BOPE Test On ARCO's Kuparuk 1Y-4 Well Sec. 1, Tll~], R9E, US~ Permit No. 83-66, On Doyon Rig No. 9. Tuesday, May 3, 1983: The BOPE test commenced at 11:00 p.m. ~nd'~as 'C~n~iUded~at- 12:30 a.m. I filled out an AO~GCC BOPE test report which is attahced. T%lere were no failures. In summary, I witnessed the successful BOPE test on ARCO's 1Y-4 Wel 1. 02-00IA(Rev. 10/79) KUPARUK ENGINEERING TRANSMITTAL # ~(~_-'~ TO' William Van Alen FROM' D.W. Bose/Shelby J. Matthews Transmitted herewith are the following. PLEASE NOTE' BL - BLUELINE, S - SEPIA, ., F - FILM~PC - PHOTOCOPY R~.I~_PT ACKNOWLEDGED: PLEASE RETURN RECEIPT · ARCO A~ASKA, A"FTN' SHELBY J. P.O. BOX 350 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 .r,~ay 6, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on May 12, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, /d .~'B./Kewl n Area Drilling Engineer JBK/GRU3L5' tw Enclosures ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER []X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 211' FNL, 1973' FWL, Sec. 1, T11N, R9E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 102' RKB 6. Lease Designation and Serial No. ADL 25641 ALK 2572 7. Permit No. 83-66 8. APl Number 50-- 029-20948 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I--~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [~X Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. ;,: .,, .~ ,... .,. ..... ~ ~ .... Estimated start: May 12,1983 *": '~' ;;~ ~'"~ '" "'::': :"~ ~'' u ''~ 14. I hereby certif~hat the foregoing is true and correct to the best of my knowledge. . Signed // Title Area Drilling Engineer The space b;J~w f~r C~r~ssio"-~'use' -- Condition/f Approva ,l~if any: Date Approved by ORIGiNAl' ~IGNEII' ,,,-'~pproved Copy Returned _ ..... By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 GRU3/SN5 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate O&G # 4 ,:/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~LY~ ~ ~-~ / y--,.¢ Location: Sec , / T I/.A/ R ~'~:C M Drilling Contractor /~ ~ ~ . Rig # . Location, General , ~.~ Wel 1 Sign 0~' General Housekeeping _ O~ Reserve pit ~ .Rig 0/~ Date. Representative Pe rmi t # ~ -- ~, ~:~ ~ / ,!/ /~/~Casing Set @- ~ Representativ~ ACCUMULATOR S'YSTEM ft. Full Charge Pressure ,.~, tO(D~ ! Pressure After Closure /7C70 BOPE Stack ; I Test Pres~sure Annular Preventer ~'~ /~;:::~1' PiPe Rams /~-~)";/-'"'/'/ L I.. :. Choke Line Valves ', H. C.R. Valve / / t · ' ~ ¢" Kill Line Valves w~¢.O(~ f~ No. Valves :- check Valve ~ / ~ No. flanges -Test Results: Failures - Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. ps.ig ps ig 200 psig Above Precharge Attained: Full Charge Pressure Attained: Controls: Master ~ Remote min ~ sec. 5. ¢ seo Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / ~Test Pressure Lower Kelly I ~est Pressure Ball Type / ~est Pressure Inside BOP ~ ~Test Pressure Choke Manifold ~ Test Pressure Adjustable Chokes / Hydrauically operated choke ~ .. / Tes~ 7I'~-~m~-~_--'i] ~--~ . ~ ~ Remarks: .... days and'~' /// Distribution orig.' - AO&GCC cc - Operator cc - Supervisor Inspector April 19, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARC~ Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re. Kuoaruk River ~ ~ · !m~t IY-4 ARCED Alaska, Inc. Permit No. 83-66 TllN ~-9E U~? Sur. Loc. 21t'FNL, !973'F%~, Sec. 1, , .... , · ..... T121-,~ RgE r~t~ole Loc. 1482'FSL, !109'FEL, Sec 36, , -~ , . Dear ~r. Ke~rin: ~n ~ ~d ' the ~ ~.c~os=~. ms approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot recovered core is required. Samples of well cuttings and a mud log are not ten,ired_.: . ~.~ continuous directional survey., is required as per 20 AAC 25.050(b)(5). If available, a tape --~'~.~ ~ the c~z~zn~ digitize~4 log info~ation shall be ~ub.n. itted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing ope-rations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Came. Pollution of.. any waters of th~. State is orohibitedt~dbY!~eAgr46" ' ~aapter... ~, ~-~rb~cie 7 an~ toe re~.ulations"_n, romul~a~. , ed th eun~ter_ (''zztl~¢ 18, Alaska Administrative Co,~,.~ Chapter 70) and b,.~ the Federal k~ater Pollution Control Act, as amended. Prior to commencine, operations you may be contacted by a representative of ~ . · the Department of Envirou~ental Coz~servation ._o aid us in scheduiinz fiel~ work, please notify this office ~a~ion ~f the blowout 24 hours prior to commencing instal Mr. Jeffrey B. ~=win Kuparuk River Unit 1Y-4 -2- April 19, 1983 prevention equipment 8o that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the .event of suspension or abandonment, please give this offlee adequate advance notification so that we may have a witness present. ~ Very truly yours, C.' V. Chatterto~¥ ORO~'a OF THE CO~".~SStON Chairman of Alaska Oil and Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be STATE OF ALASKA ALASKA L.,- AND GAS CONSERVATION CC. _.,vllSSlON PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. 2. Name of operator DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ~ SINGLE ZONE [~X ~,~r~ MULTIPLE ZONE [] ':/~ ~ ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 211' FNL, 1973' FWL, Sec. 1, TllN, R9E, UM -At top of proposed producing interval 1236' FSL, 1429' FEL, Sec. 36, T12N, R9E, UM At fotal depth 1482' FSL, 1109' FEL, Sec. 36, T12N, RgE, UM Kuparuk River Unit c~ 10. Well number ~u~' 1Y-4 u~. 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. PAD 66', RKB 102' I ADL 25641 ALK 2572 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 211' FNL ~ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures 2802 MAXIMUM HOLE ANGLE 40 o (see 20 AAC 25.035 (c) (2) 321,5 Proposed Casing, Liner and Cementing Program 16. Proposed depth (MD & TVD) 7442' MD, 6485' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2500 feet. 21 5. Distance to nearest drilling or completed 1Y-3 well 60' ~ surface feet 8. Approximate spud date 05/01183 psig@ 80°F Surface psig@ 6_3~2 ft. TD (TVD) SIZE ,. Hole . Casing ~4" 16" ~ 3-1/2" 10-3/4" j8-1/2" 7" Weight 65# 45.5# 26# 22. Describe proposed program: :ASlNG AND LINER Grade Couplingl Length H-40 Welded I HF-ERW BTC I 7409' ij-55 I SETTING DEPTH MD TOP TVD 80' 36' I 36' 2165' 35' I 35' I I 33' I 33' MD BOTTOM TVD 116'1t 116' 2200' 2200' I I 7442' 16485' I I QUANTITY OF CEMENT (include stage data) 300 c.f. 1000 sx ext. Perm & 250 sx Perm. C 360 sx Class "G"extended 340 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7442' MD, (6485' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon instal]ation and weekly thereafter. Test.pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2802 psig. Pressure calculations are based on current reservoir pressure. Surface )ressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. Estimated top of cement on 7" casing string is calculated to be 2354' MD which is 500' MD above top of West Sak Sands. If hydrocarbons are detected in the Ugnu Sands, cement wil] be brought up to 500' above top of the Ugnu,-Sands or the shoe of the 10-3/4i' casing (2200' MD)). 1Y-3 will be 60' away from 1Y-4 at th~,~/urface. The~; c~u/,rses are divergent from there and there are no closer wellbores ~pyw~ere d ownhole. (./~;'L4.; ~',/~ T ITLl~rea Dri 11 i ng Engi neer DATE , ~'.//¢~',~ The space be,o~/C~,ssi~'use-- ' - / CONDITIONS OF APPROVAL Samples r. equired []YES [~NO Permit number APPROVED B~ Form 10~01 GRU1/PD17 Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE April 19, 1983 by order of the Commission Submit in triplicate Surface Diyer~'- System '(9. L 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" .bell,,nipple. 16" Conductor 3~ Close annular preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under ans. circumstances. Maintenance & Operation ~ 1. Upon initial installation close annular I preventer and verify that ball valves ! ' have opened properly. · I 2. Close annular preventer and blow air ~ . through diverter lines every 12 hours. ]_3-_~./8" 5000 PS1 ~RSRRA BOP STRUCK f, ANNUL.qR PREVENTOR ) . 2. 3. 4. 5~ f) 'z () ..- _' DRiLLiNG ~ -- SPOOL ' 6 ) ( PiPE...RnHS ) ' "s -( . 3o 16" Bradenhead 16" 2000 PSI x lO" S-~'~3 FSI casing head 10" 3000 PSI tubing head lO'" 3000 PSI x 13-5/B= 5~00 FSI .. adapter spool 13-5/8" 5000 PSI pipe ra:s 13-5/8" 5000 PSI dritl~n~ s-pool w/chok, e and kill lines -.~ - . · 13-5/8" 5000 PSI pipe rams- _-.__.. - 13-5/8" 5000 PSI blind ram_s . 13-5/8" 5000 PSI anp-,alar '- -- _ _ _ .. -. - - _ ACCL~-IULATOR 'C. JJ:~A£II'1r TF_ST C4£CK ~ FILL P, CC~.q. AYOR -~--...SERI~I~- l~ P~P~ WI~ 1500 PSI ~~g~ ~ ~r~ ~~R_ ~S~YE TIHE T~ C~E ~ ~ITS S~Y~- ~LY ~qD RECO?~ ~ T~ ~ ?RF~S~ ~I~ ' ~ OFF. ~ ON I~C R~PX. ~ ~.~~ ' ~IT IS 45 SE~;~ ~I~ T~E ~ 1~ PSI ~ ~NI.o PP~SU~. . 13-5/8" ~07 ST~< TE~ ~LL BOP STA~ ~';D M~NI~ ~I~ ~C DI~EL. ~E~ ~JT ~ HO~ ~ S~ A~ ~Y F~- WI~ S~T A~ S~T I~; ~~D. ~ I~ L~ ~N SCOWS IN H~. ~E ~3C;U~, PR~;~R ~D ~ ~ ~?~S Y~V~ O~t 1.~q I FOLD. ~T ALL Cgq~;l~gS TO ~ ~I ~0 lO HIll.S. ~o ~uT~s. ~L~g~ TO ~0 ~. ~ V~V~ OI~f ~~'~ OF ~. - B~ED ~,~tlST~{~*-PP~L~ ~ ZERO ~o ~o ~s~. - ' _ - ~t iOP S~ OF PiPE ~ ~ ~-~% S~ ¢ PIPE ~S. It;~E PRESSUPZ TO 3~ ~ ~D ~ D ~p, lO M!!~Ji~. B~ED lO Z~ PSI. ~'- P~D IESI lO 3~ ~I F~ lO ~~. B~D IO ZERO PSI. ' ~I~I. ' _ Wt~ ~ P~.. : P~ TEST [~;F~II~ ~ ~~ Yt~R. ' - ARCO Alaska, Inc. ~"'~--. Post Office B~._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 14, 1983 Mr. C. V. Chatterton Commissioner State of~aska Alaska Oil & Gas Conservation Commission 3001 Porcumine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-4 Dear F~. Chatterton" Enclosed are' An application for Permit to Drill Kuparuk 1Y-4, along with a $100- ~lication fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on Hay 1, 1983, your earliest ~pproval will be ~preciated. If you have any questions, please call me at 263-4970. Sincere ly, .~sB~~g Engineer JBK/JG:bc Attachments Alaska Oil & Gas ~,onu, CommissioD Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany :55 :56_~ __L_OCATE O IN I '1 200' -.; PROTRACTED S_EC,!,'.'rw.P.. liN,, RGE, 9 E,_,UMI.A..T_M_ER!DI~.N.:. RESERVE .PIT RESERVE PIT PHASE ! .~.~ -.~.. ::.._, II ,.:-:. · ._ '1. Y=597§115. X= 551460.24 LAT. 70° 20*$5.0524" LONG. 149° 44'40.818" 211 ' FNL , 1792' FWL 2. Y=5975115.30 X= 531520.06 LAT. 70° ?0':55.0296' LO NG. 149°44' :59.070" 211' FN L,. 1852' FWL :5. Y" §975115.:54 I ,I 4. Y= 5975115.44 X= 53164;0.45 LAT. 70° ;~0' 35.0260" LONG. 149°4'4* $5.552" RESERVE, PIT . ,, 380' ' 2 I1' FNL~ 1975' FWL 5.Y= 5 974755.49 X= 53 164~,4:5 . LAT, 70°20 31,4857 LONG. 149 o 44* ,35.597 571' FNL, 1971 FWL 6. Y' 5974755.48 7. Y~ 5974755,BI X= 5:51§2~21 u Kup~ruh [.roJact LAT. 70°20 ~1,41)09 LONG. 149°44~ :59. I10" ~ ' 571' FNL,1851' FWL · , "8. Y"Se?4758.4~ SUF~VEY I 12 D,S. X= 5:51580.12 L AT. 70° 20' :55.0275" LONG. 149044*37. 315" 2 I1' FNL ~ 1912' FWL VICINITY MAP Scale': I"=lml. NOTES:' · 1, ALL Y fl X COORDINATES ARE ALASKA~. STATE PLANE~ ZONE 4, ~. DISTANCES' TO SECTION LINES ARE GEODETIC. 3. SEE REF.. DWG. 22908, SHl'. 7Y-12-3OOI,REV. 7A. 4. DRILL SITE AND Y.8~ X COORDII',',%TE$ ARE BASED ON MONUL'.~NTS I.Y EAST AND' I.Y MIDDLE BY LHD ASSOCIATES, 5. EL. BASED ON MON. I.YMIDDLE BY t.~t[} A$SOC SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTEI:IED AI'.JD ,. LICENSED TO PRACTICE LAHD SUi%~7_YINB IN ,THE STATE OF ~ ALASKA~ AND THAT THIS PLAT'REPF;"":SENT~ A SURVEY MADE UNDER MY DIRECT SUPERVISION~ ANDTH~T ALL DETAIL:3 ARE CORRECT AS OF' MARCH I, 19 8:5. _ . ARCO ska, Inc. North Slope Drlllln~ D.S, IY CONDUCTORS ',: AS gUlLY LOCATIONS PHASE I - i ii . X" 5:31580.41 : X~ .551460.§2 ......... -_: - .... - .... .. ,,,o: LONG. 149044' ~7. 351 ' LONG· 149°~'40.8 571' FNL~ 1911' FWL 570' EN L~1791' FWL [ dwg. no.9.05 '°5.12d28 ,.m,,., ~ uN ,~v,~ L drawn by: J.B.' . .... ,,, CHECKLIST FOR NEW WELL PERMITS ,, Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) no c U,K. 7vJ- f2 //2 thru 8) (3) Admin ~~ '~{" {O'Q~3 (9~ thru 11) ...... (4) Casg ,/z)-Y ~/-/zP-~ (12 thru 20) ( s ) //,I// (21 thru 24) (6) Add: YES NO 1. IS the permit fee attached ................... : .......... 2, Is Wel.l' to be located in a defined pool 3, Is well located proper distance from property line .... 4, Is well located proper distance from other wells , 5. Is Sufficient undedicated acreage available in this poo 6. Is'well to be deviated and is well bore plat included 7. Is operator the only 'affected party .., ................ 8. Can permit be apprOved before ten-day wait .............. 9. Does operator have a b°nd in force . ................................. 10. Is a conservation order needed ...................................... 11 Is administrative approval needed · ~ e · ® · · · · · · · · · · · · · · · ® m · · · · · ·, · · · · · · · 1 2'· 13. 14. 1'5· 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS Is conductor string provided ........................................ ~z~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in Surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~. Will surface casing protect fresh water zones .. . ~ Will all casing give adequate safety in collapsei"[g~gig~'~ ~g[][ AZ# Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... '.'~'"zT/~ Is a diverter system required ....................................... ~/ Are necessary diagrams of diverter and BOP equipment attached ....... ~$f~i DoCs BOPE have sufficient pressure rating - Test to 3~TZrf3 psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~f~. Geology: Engin~ g~ing: 'ev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl .. No special'effort has been made to chronologically organize this category of information. ,o LIS TAPE VERIFICATION LISTING ~P OJ0.H02 YERIFICATION LISTING PAG~ I * REML HEADER ATE ~83/05/16 ONTINIIATION ~ REVIOUS REEL O~MEN?$ :LIBRARY TAPE * TAPE HKADEP ** RI~IN ~0000 R£VIOUS TAPE ~ OM~ENTS :LIBRARY TAPE EOF * FILE HEADER ** ILE NAME ~SERVIC,O0~ ERSION ~ ATE : A×IM[)~ LENGTH : 1024, ILE TYPE REVIDI.1S FILE * INFORMATION RECORDS ** CONTENTS !N : 1Y'4 ~ANG~ gE 'OWN: lin ;ECT~ ITAT~ ALASKA ~T~Y~ USA :* COM~EwTS ** UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 O04 O65 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 ,VP 010.HO~ VERIFICATION LIS, TING PAGE 2 ~OB ~UN ,DP SCHLUMBERGER A[~ASK,A CO~PHTCING CENTER PANY = ATI~AMTIC RICHFIE[,D COMPANY LD = KUPARUK NTY = NORTH SbOPE BOROUGH TM = DATE [,OG:~:[):: 08'MAY-83 !YPE {ATR N~ = 9.6~5" SURFACE TO F £, U I D = × C' P:131., Y M E ~ SIZE = 8 5" OS~TY = 48,0 S ~ 10[o D LOSS = 5. C3 IX SANDSTONE rp 010,H02 VE:RIFIC~:TION LISTINd PAgE 3 ~ DAT~ FORMAT RECORD ** ~TRY BLOCKS TYP~ SIZ~ REPR COD£66 ENTRY1 0 1 66 0 ~ N {TUM SPECIFICA~[IO BLOCKS ID EPT FLU OIL R DIb PHI FDN RMO FDN NOB FDN CNL FDN CMl, FDN AL! FON R FDN RAT FDN N~A FDN ORDER . LOG TYPE CLASS MOD NO. bEVEL COD~ ~? o o o o o 4 o , o 4 o , 0 4 0 0 ~ 0 1 68 0 0 1 G/c3 42 44 0 0 0 4 0 1 G/C~ 4~ 35 1 0 0 4 0 ! CPS 42 34 92 0 0 4 0 ~ 68 CPS 42 34 93 0 0 4 0 ~ 68 IN 42 2~ 3 0 0 4 0 ! 68 42 42 1 0 0 4 0 ! 68 42 0 0 0 0 4 0 I 68 EPT PHI CNL NRA 7431,5000 '35,0313 34,7656 263,7500 3,3301 EPT P PHI CNL NRa 7400 0000 SFLU -9 0313 GR 34 7168 DRHO 263 7500 CALI 3 3301 ,EPT ,P 'PHI :NRA 7300 0000 gFLII -8 1172 OR 44 0918 DRHO 494 0000 CaL! 3 ~0~6 4 0273 IbM 2,6621 ILD 2,~1864 37:8750 DT 99,3750 GR 83, 75 0,1113 RHOB 2,4902 NCNb 878,5000 8,8047 GR 37.8750 NRAT 3,037~ 3,1660 ILM 2,3750 ILD 2,3223 92,8750 DT 108,1875 GR 91,6250 0,i]62 RHOB 2,4355 NCNb 1882,0000 ~,9297 GR 92,8750 NRAT 3,5684 IP OlO,HO2 VERIFiCaTION I, ISTING PAGE 4 ~PT 7200 32 900 7100 -19 39 ~NL 7000 9 90] EPT 6900. P -25, PHI 23. CN~ NR~ EPT 6800 P PHI CNb 169~ EPT 6700 P PHI 50 CNL 421 EPT 6600 P -20 PHI -999 CNI., -999 NRA -999 '~PT 6500 ~ -24 'PHI -999 'CNb -999 ,NWA -999 ,EPT 6400. ,P -29. IPH! -099. 'CNL -99q. [NRA -999. 0000 SFLU 6094, GR 2266 DRHO 5080 CALl ]0 8 0000 SFLU 5469 G~ 2578 DRHO 0000 CALl 5859 0000 SFLU 34.. DRHO ~§00 CALl 94 0000 313 793 ORHO 0000 CALl 7129 0000 5313 GR 1426 DRHU 0000 C~LI 6621 0000 SFLU 03t3 GR 0977 DRHO 0000 CaLl 0508 0000 SFbU 0313 GR 2500 ORH0 2500 CILI 2500 0000 SFLU 0313 GR 2500 DRHO 2500 CALl 7500 0000 SFLU 0313 ~R 2500 DRHO ?500 CALI 2500 9,734:4 6~,5000 DT ,0156 RHOB 9.0703 3,0605 IbM g~,3125 DT 9 ' 0430 RHOB ,9766 ~R 9,0313 IbM .028 9.3203 UR 6 7695 IbM 670i6875 DT 0~98 RHOB 9,3047 C,R 6563 9,2891 1,8350 IbM 97,6250 DT O,O~gB RHOB 10.8125 CR 1,9453 !1.7,4375 DT -999,~500 RHOB 10,8994. GR 11.3516 IbM 2!6.7500 DT -999,2500 RHOB 10,5781 GR 3,8047 IbM 125,4375 DT -999,2500 RHOB 10,8359 GR 7,26 6 It, D , 38 NCNb 67.5000 NR~.T 2,6992 94,3750 GR ~.4336 NCNb 92,3125 6,4297 lbo 8~,7500 GR .37:89 NCNb 75,1250 NRAT 4.'/422 IhD 8g,7500 GR 2.4355 NCNb 67,6875 NRAT 20 3594 lbo 83~0000 GR 2,7090 NCNb 45,7813 NR~T 1,~238 12~, 500 97,2930 NCNb ,6250 NRAT 1,6895 IbD 118,7500 GR -999,2500 NCNb 117,4375 NRAT 2,705! IbD 108,5625 GR -999,2500 NCNb 216,7500 NRAT 2,7949 IbD 112,7500 GR -999,2500 NCNI, {25,4375 NRAT 2974 O0 0 2 9355 2,78S2 7~,6875 219 ,0000 3.3848 3 6 7 437~ ' 5 4 9609 , 000 ,3906 lB 4688 43i7188 4520 ~000 2, 129 1,3340 86,0625 1707,0000 4,0469 .,oA: 00 -999,2500 2.6016 206,2500 ;g99,2500 999,2500 2.7539 117,1875 -999,25O0 =999.2500 VP 010,H02 VERIFICATION LXMTING PAGE EPT 6300 P PHI -999 CML -999 NRA -999 6200 -29 -999 -999 '999 P -28 PHI -099 CNL '999 NRA -999 EP? 6OOO P pM! -999 CNL -~9~ N~A -999 EPT 5900 P -37 PHI -999 CMl. -099 N~A -999 MPT 5800 P -50 PHI -999 CNL -999 MmA -999 ~PT 5700. ? -]6. PH! -999. C.Nb 999 5600 -33 -999 -999 -999 0000 5313 2500 2500 2500 1,8662 .1.24,0375 DT 10.4766 0000 5313 2500 2500 2500 SF:bU 5,4:766 Ib~ GR 97,81~5 DT PR~O R~O:B C~[,I 10,7500 GR SFLU 3,298:8 IL" C.R 113,1250 DT DRMO ..999,250:0 RHOB C,.A,,~ I 11 , 3594 G~ 0000 S~LU 0:313 GR 2500 OReO 500 CALI 5OO 0000 SFI.U 531.3 GR 2500 DRHO 2500 C~LI 2500 4,2305 94,0000 DT -999'~500 RMOB 10.~187 GR 0000 SFLIJ 0313 ~ 2500 DRHn 2500 CAI.I 2500 4,2500 .133,3750 DT 999.2500 ~HOB 11,~109 0000 SFLL] 531] GR 2500 DRH0 2500 C~I 2500 4 1250 125i9375 DT -999 2500 RHOB 11.7422 0000 SFLU 031.3 ~R 2500 D~Hn ~500 CALl 2500 2,7793 lbN 1.47.5000 DT -999,2500 RWOB 10,7578 ~ EPT 5500 0000 SFLU P -49' PHI .999,53~3 GR , . ,2500 DRHO 'CNL -999.2500 CA~.I NRA -999.~500 4,8047 IL" 145,6250 DT -999,2500 RHOB 9,9141 GR 6,3086 IbM 180.5000 DT -999.2500 RHOB !.0.7734 ~P 1'~6 GR 114, '999,2500 NCNb 124.9375 N~AT 3,5098 IbO 9,~g.187~) GR '250 97,8125 NRAT 2,8730 ILO : .ooooo -g ,250 NCNb 11.3,1250 NR. AT 2.7891 t06,3750 '999.~:500 NCNb 94,0000 NRAT 3,3672 ILO 110,7500 GR '999,2500 NCNb 133,3750 NPAT 3,2637 XbD 144,1875 '9 ,2500 NCNb 125,9375 I~RA, T 1,8096 114,3750 GR -999.2500 NCNb 147,5000 1,9404 XbD 113,5625 GR -99~.~500 NCNb 1.45,6250 N~AT 4.2813 XbD 103,0000 GR '999,2500 NCNb 180.5000 N~AT 1 5098 134 125 -m99 ~500 3,4492 ~,1250 -99 ,2500 -999,~500 2,8262 119,~,]75 -999, 00 -999,2500 2'8!25 1.00, '999,2500 -999,2500 3 3945 1393i0000 -.99 2500 999.2500 3.2871 121 0625 -999:2500 -999,2500 1,7852 163,3750 -999.2500 -999.2500 1.9199 145,8750 '999.2500 -999.2500 4 1836 165i7500 -999 ~500 -999,2500 VP Ot0,}.{O2 VF~{:{IFICATIOt~{ LISTING PAGE 6 EPT 5~00,0000 SFLU P 40,0313 PHI -999,2500 CNL -999,2500 {RA EP... 5300 PHI -999 N~A -9 5200 PH! -99:9 CNL -999 ~RA 'ggg EPT 5100 P 44 PHI 'qqq CNh -999 NRA -999 EPT §000 P -46 PHI CNt, -09~ NRA -99 £P? 4900 P -50 PHI -999 'CNB -999 N~A -999 EPT P PHI CNB EPT P EPT P PHI NRA 0000 0313 2500 ~500 C~LI 0000 SVLU 313 GR 500 DRHO 2500 CALl 2500 0000 SFLU 031,3 GR 2500 r3:~HC1 500 CALI 5OO 0000 SFI,U 313 GR 500 DRHO 2500 CALl 2500 0000 SFLU 0313 GP 2500 DRHO 2500 CALI 2500 4'.8,00i0000 58 5313 -999 2500 -9gg 2500 -999:~500 4700 -999 -999 -999 4600 -999 -999 -999 0000 0313 2500 2500 2500 ,0000 5313 .2500 ,2500 ,2500 SFLU ORHO CALl SFLU DRH~ CALl SFLU ~R ORHO CALl 2 8887 "999. 500 RHOB 10.7578 3,3203 81,125~ DT -999,~50 10,t406 2 7676 9~' .99~.,3125 DT .2500 ~HOB 10.3672 3,1777 16~ 89,1875 DT -099,~500 R~OB i0.2578 GR 3 6'64{ IL~ 80i9375 DT -999 2500 RHOB 10,~641 ~ 3.9707 IBM 123,3125 DY '999,2500 ~HOB 10.6484 GR 4,0742 IBM 76.5000 DT -999,2500 ~HOB 10,0391 ~R 3.0527 ILM 82.7500 DT -999,2500 RHOR i0,64~4 G~ 3,4336 IbM 78,5000 10,7344 GR 2,0000 ILD 104,3750 GR · '999,~500 NCNB 102,8750 NRAT 2 650:4 98:1875 GR -999,~500 NCNB ..RA~ B~.1250 ~ ' 51.56 NCNb 92.3125 NRA? 2.6211 .~02 1875 q9~2500 NCNb 89,1875 MRAT 2 8223 IbD 88i7500 GR -999 ~500 NCNL 80,9375 NRAT 2.8711 IbD 106.0000 GR -999.2500 NCNB 123,3125 NRAT 3,5859 ILD' 95 1875 GR -099:2500 NCNB 76,5000 N~AT 2,4004 107,0000 -999,2500 NCNb 82,7500 2.6016 ILD 105.5625 GR -999.~500 NCNL 78,5000 NRAT 9932 500 -999.2500 2 6973 80 8t25 -999 2500 -999 ~,500 2,5234 8 ,6875 'gg ,2500 -gg ,2500 2,6758 85.0000 -999,2500 -999,~500 2 9004 , 5 '999, 0 ..999.2500 2,9082 .115.4375 999.2,500 -999,2500 3 3457 69:0000 -999.2500 -999,2500 2.4609 73,2500 .-999,~500 999,2500 2,7813 72,0000 '999.~500 '999.2500 IP OIO,H02 VERIFICATION LISTING PAGE 4500 0000 SFbU 3 -999,25 DRMO -99 -999, 500 CABI 10 -999, 500 EPT 4400 ~ .'51 PHI '999 'N ~999 NRA 999 EPT 4300 p -57 PHI -999 CNL -999 NRA -999 4200 .-60 999 -999 -999 EP? 4100 P -64 PHI -999 e.,. :g99 NRA .. 99 EPT 400O P PHI -999 CN[, -999 NRA -999 EPT 3900 PHI 9 CNL ,~999 NRA -999 '£PT 3800 P -65 PHI -999 ~CNL -999 :NRA -999 [PHI 999 'CNL -999 :~RA -999 3066 Ih~ 06~5 DT 2500 RSOB 9219 GR 0000 S~'l..J 3,1191 IbM 0313 GR 73,56~5 DT 25'00 DRHO :-999,2500 RHOB 2500 CALl 1,1.1016 G~ ~500 0000 ~:FLU 2,7500 I:LN 5,313 GR . 80,1R75 DT 2500 ORHO :999,2500 RHO[% 2500 C~LI 11,, 1797 ~R 2500 i 000 SFLU 5, 113~ IbM 313 GR 96,8125 DT 500 DRHO ..999,2500 ~HOB 2500 C,LI 11,0i56 ~, 2500 0000 SFhU 4,039:1 IbM 500 ORHO -99 500 RHOB 2500 CALI 1 1250 2500 0000 SFLU 3.2383 IbM 53i3 GR 99,3750 DT 2.500 DRHO -999,2500 RH. OB 2500 CAbI 1~,5469 GR 2500 0000 SFLU 3,0742 IbM 5313 Gq 50,3125 DT 2500 DRHO -999,2500 RHOB 2500 C~LI 12,0234 ~R 2500 0000 SFI, U 4,0313 0625 GR 89,5625 PT 2500 DRHO -999.2500 2500 C~I.I 12.0313 2500 0000 SFGU 3,7637 Xb~ 06~5 GR 8~,8125 DT 2500 DRHO -999,~500 ~HOE 2500 C~LI 12,2031 GR 25OO 2 5000 II.,D 1061187~ GR -999 2500 NCNb 75,06~5 NRAT 2,5 i:56 XLD . NCNb 71 ~625 N~AT 2.3926 .111,~000 GR 999, 500 NCNb 80.1875 3.0000 108,7500 GR -9:99 -2500 NCNb g6,8125 NRA. T 4,6758 .108.5625 999,2500 NCNb 85,0625 ~RAT 2,617~ IhD 12~,~50 GR -99 , .500 NCNb 99,3750 NRAT 0~,~879 12 , 875 GR 50O NCNb '99590:3125 NR~T 3,0273 XbD 115,7500 GR '999,2500 NCNb 89,5625 NRAT 2,4102 IbD 123,5625 GR -999,2500 NCNb ~2,8125 2 ,. 5?03 · , 74 .999'~175 , O0 999,2500 2,6367 999, .,999,2500 -999.2500 3,0898 75,6~50 -999 I2500 -999,2500 3,408.2 -99 ,2 -999,2500 86, -999,2500 -999,2500 3,0957 71,3125 '999,~500 '999, 500 3.2422 71.0000 -.999.2500 999,2500 2,5078 96,2500 -999,2500 -999,2500 VP 010.HO2 VERIFTCATIO{'~ LISTING PAGE 8 EPT 3600 P -73 PHI -999 CNL -909 NRA -999 MPT 3500 P PHI 37 CNL 561 NRA 3 HPT 3400 P -22 PHI 39 CNL 471 ~R.A 3 ~PT 3300 P -26 PHI 44 CNL 444 EP? 3200 ~CNL 424 NRA 4 EPT 3100 P -36 PHI 45 CNL 392 NRA 4 0000 SFLU DRHD 500 CAY~I 5 0 0 0000 SFLU 465 0000 601.6 0000 SFLU 84.37 GR 7949 DRHO 5000 CALI 8477 0000 3438 GR ~871 DRHO 2500 C~LI 0000 SFLU 4063 UR 5781 DRHO 750O CALI 0703 0000 S~'LU 7188 GR 1172 DRHO 5000 CAT..,! 3555 ,EPT 2900 ,P -61 !PHI 46 'CNL 413 0000 SFLU 7813 ~R 533~ DRHD 0000 CAI,I 1719 ,EPT 2800,0000 SrbU IPHI 42,0998 DRH0 'CNL 459,0000 CILI 'NRA 3,6016 -999 500 ~HOB 11,8750 GR 5,1719 IE,~ 6~,2500 DT .0435 ~HOB 11,4922 GR 4,7227 IL:~ 6~,1250 DT ,0366 RHOB 11,7500 GR 3,7441 IL~ 7~,9375 DT ,0234 RHOF 12'3984 CR 7,3164 IbM 1875 DT 7 '0552 RHOB 19'2500 GR 7 0078 69i8750 DT 0 0459 11 1.484 GR 8.0938 Ib~ 82,5625 PT 0.0581 RHOB 12.81~5 GR 13,6563 41,3438 0,0098 RHOB 10.3672 ,9375 DT 0,0200 PHOB 10,~578 GR .!.2~ 791.05625 999i2500 NCNb 6~,1875 NRA? 5.7148 IbD 1,1~,1875 GR ,2500 NCNb 65,2500 ~AT 4 0977 ILD ,.2~.!7500 GR {621 NCNb 73,9375 NRAT 6,]555 ILD 122.5625 GR }.2363 NCNb 71..1875 NRAT 5,3359 IbD 126,3750 GR 2,2227 NCNL 69,8750 NRAT 7,4102 ILD 82,56~5 NRAT 10.1328 ILD 135.0000 GR 2.0781 NCNL 41.3438 NRAT 10.6016 135.0000 GR 2.1602 NCNL 68.9375 4, O039 -g99, -999,~500 5.9336 64 1250 202~' .0000 " 3770 . 4,9336 59.1562 1815.0000 3,5039 4 8:047 70.81~5 1849.0000 3,7695 6.953i 73,56~5 1730.00 0 3.6699 5,6680 69,7500 1.0000 1713,783~ 8.0313 83.8750 1789.0000 3.6016 10.5625 42,9375 1723.0000 3,8223 11.0859 70,8750 1650.0000 3.5664 IP OtO.H02 V~RIFIChTION LISTING PA~E 9 ~PT F~PT ~RA CNL CNL P PHI CNL ~700 0000 4O600.06 4 24 ~ SFLU GR C 2600 0000 SFLU -40 34.38 GR 41 6992 Dr:Ho 376 ~5oo cAI.! 4 o0o 2500 0000 SFLU -46 ~687 5; 207 DRHO 00005000 2400'0000 -52 ~500 57 707 301 5000 4 6992 $ F h U Ctl.,I 2300 0000 SFI~U -38 406] GR 47 6563 DRHO 337 0000 CALl 4 4531 2~36 0000 -1 8008 57 4707 268 5000 5 1172 SFLU DRHO 1,5,4B44 ILM 4~,8125 PT .0142 i~HOB 1.2.4375 GR DT R:HOB 11 6172 GR 5,3672 : IbM 6~,0000 DT .0~81 RHOB 11.0703 GR 11,4844 4 ,9062 DT ~,0063 16,1094 42 ~437 DT 0 244 RHOB 14 5000 CR 2000,0000 34,2187 DT -0,5435 RHOH 10,4766 16,3438 IbD 33,3750 GR 2:80234 NCNI, ~3 125 NRAT 7 ,.4258 ILD 13~.3750 GR, .,1719 NCNb 66,9375 NRAT 7,2 ! $ 7 I bD 14~.7500 GR * 105 5 NCNb 6~,0000 NRAT 1~I,3594 I{hD ,3750 ~ ~ .:63:67 NCNb 49,9062 NRAT 7.i13] lbo 143,7500 (;R 2.1191 NCNb 42,8437 NRAT 2000,0000 ILD -999,2500 GR 1,7510 NCNb 34,2187 NR~.T 1~ 1719 1724 ],9902 9,0703 15 ,0000 3,6055 8.3984 '117~ 12,3984 44,906~ 1411,0000 ,5977 8,4375 40 75 o,:o ooo 4,0117 168,0000 -q99,2500 1374,0000 4,4375 * FILE TRAII.,ER ** ILE NAME :$ERVIC,O0I ERVI¢~ NAME ER$ION # ATE ~ ~XI~IIM LENGTH I 1024 ILE TYPE ~XT FILE NAM~ EOF :* TAPE TRAILER ;ERVlC[ NAME ~ATE 1R3/05/16 ~RIGIN {0000 VP 010,H02 VERIFICATION LISTING P~GE 10 ONTINUATION # OM~£NTS ~LIBRARY TAPE * REEL TRAILER ** ERVICE NaME ~$MRVIC ,ATE 583105/16 ~RIGIN : .ONTINLAT,ION # ~O~MENTS ~I, IBRARY TAPE ********** EOF *******~** ~*******$* EOF ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MMeemmoorryy MMaaggnneettiicc TThhiicckknneessss TTooooll LLoogg RReessuullttss SSuummmmaarryy Company: ConocoPhillips Alaska, Inc. Well: 1Y-04 Log Date: October 26, 2014 Field: Kuparuk Log No.: 14636 State: Alaska Run No.: 1 API No. 50-029-20948-00 Pipe Description: 3.5 inch 9.3 lb. J-55 BTC AB-MOD Top Log Interval: 2,254 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 6,655 Ft. (MD) (MTT only) Pipe Description: 7 inch 26 lb. J-55 Top Log Interval: 2,254 Ft. (MD) Pipe Use: Production Casing Bottom Log Interval: 6,655 Ft. (MD) (MTT only) Inspection Type : Production Casing Damage Inspection COMMENTS : This MTT data is tied into the bottom of the surface casing at 2,254 feet (Driller’s Depth). This is the first time a 12 Arm Magnetic Thickness Tool (MTT) has been run in this well. The MTT responds to the metal surrounding the tool, including the 3.5 inch tubing and 7 inch production casing. A pass at 10Hz was made at 20 fpm from 2,254 feet (bottom of surface casing) to 6,655 feet. INTERPRETATION OF MTT LOG RESULTS : The MTT metal volume assessment covers the interval below the surface casing from 2,254 to 6,655 ft. Due to the concentric pipe strings in the log interval, the MTT response is qualitative – indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. High frequency signal oscillations in the individual sensor curves are generally associated with tubing damage, while low frequency deviations in the overall metal thickness measurement point to metal loss in the production casing. Changes in metal volume are relative to the calibration point at 4,767 feet, where the readings are assumed to represent undamaged pipe. All other readings are relative to this reference point, which include influences from the 3.5 inch tubing and 7 inch production casing. A plot of the 10Hz MTT recordings is included in this report. A continuous line of high frequency signal oscillations is recorded across the interval logged. This pattern of high frequency signal oscillations indicates possible damage to the tubing. Low frequency deflections in the individual sensor traces indicating possible casing damage are observed in the intervals from 4,574 feet to 4,578 feet and from 4,768 feet to 4,781 feet, with maximum metal loss of ~8% metal volume in each interval. Most of the variances apparent in the overall delta metal thickness curve appear to be associated with manufacturing aspects of the tubing and casing joints. Detailed log plots of the damage recorded by the 10Hz MTT pass from 3,440 feet to 3,590 feet and from 4,540 feet to 4,840 feet are included in this report. The percent circumferential metal loss expressed in this summary is a percentage of the total metal the tool is responding to, which includes influences from the 3.5 inch tubing and 7 inch production casing. If all of the metal loss is specific to the 7 inch production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. T. Leckband J. Bruning, J. Burton E. Zumba Field Engineer(s) Analyst(s) Witness(es) SSSV (1821-1822, OD:3.500) SBR (6633-6634, OD:3.500) PKR (6658-6659, OD:6.156) PKR (6894-6895, OD:6.156) SLEEVE-C (7009-7010, OD:2.750) PKR (7019-7020, OD:6.156) Perf (7124-7140) Perf (7122-7142) Perf (7158-7178) 1Y-04 API:500292094800 Well Type:INJ Angle @ TS:35 deg @ 6797 SSSV Type:TRDP Orig Completion:5/10/1983 Angle @ TD:35 deg @ 7420 Annular Fluid:Last W/O:3/14/1987 Rev Reason:TAG FILL Reference Log:Ref Log Date:Last Update:7/11/2005 Last Tag:7142 TD:7420 ftKB Last Tag Date:7/5/2005 Max Hole Angle:47 deg @ 4500 Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 78 78 62.80 H-40 SUR. CASING 10.750 0 2254 2254 45.50 K-55 PROD. CASING 7.000 0 7394 6515 26.00 J-55 Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 3.500 0 6602 5868 9.20 J-55 BTC AB-MOD 3.500 6602 7028 6216 9.30 J-55 EUE 8RD AB-MOD 2.875 7028 7047 6232 6.50 EUE 8RD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 6797 - 6857 6028 - 6077 C-4,C-3 60 12 5/23/1983 APERF 5.5" SOS high density 6908 - 6939 6119 - 6144 C-1,UNIT B 31 12 5/23/1983 APERF 5.5" SOS high density 7122 - 7124 6293 - 6295 A-4 2 12 5/23/1983 RPERF 5.5" SOS high density 7124 - 7140 6295 - 6308 A-4 16 16 4/4/1993 IPERF 2 1/8" Enerjet; 0 deg. Ph 7140 - 7142 6308 - 6309 A-4 2 12 5/23/1983 RPERF 5.5" SOS high density 7158 - 7178 6322 - 6339 A-3 20 12 5/23/1983 APERF 5.5" SOS high density Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2519 2519 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 4/2/1993 2 3645 3605 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 10/23/1993 3 4120 4010 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 3/2/1988 4 4592 4356 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 4/2/1993 5 5066 4686 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 3/14/1987 6 5540 5029 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 4/2/1993 7 5985 5370 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 3/14/1993 8 6398 5701 Camco 3.5 X 1 DMY 1.0 BK 0.000 0 3/14/1987 9 6593 5861 Otis 'LBX'DMY 1.5 RO-5 0.000 0 3/2/1987 Injection Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 10 6699 5948 Otis 'LBX'DMY 1.5 RM 0.000 0 6/17/2003 Closed 11 6771 6007 Otis 'LBX'DMY 1.5 RM 0.000 0 6/17/2003 Closed 12 6877 6093 Otis 'LBX'DMY 1.5 RM 0.000 0 5/31/1998 Closed 13 6972 6171 Camco 3.5 X 1.5 DMY 1.0 BK 0.000 0 7/10/1993 Closed Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 1821 1821 SSSV Camco TRDP-1A-ENC 2.813 6633 5894 SBR Camco OEJ 2.813 6658 5914 PKR Camco HRP-1-SP 2.859 6894 6107 PKR Camco HRP-1-SP 2.859 7009 6201 NIP AVA. NIPPLE 2.750 7009 6201 SLEEVE-C AVA; BPI SET 6/17/2003 2.320 7019 6209 PKR Baker 'FB-1'3.000 7036 6223 NIP Camco 'D' Nipple NO GO 2.250 7046 6231 SOS Camco 2.441 7047 6232 TTL 2.441 Fish - FISH Depth Description Comment 7220 Valve Assy & Nozzle 2' Double Check Valve Assy. & Nozzle from Coil - Downhole 7274 1 1/2" DMY See WSR for details (11/1/92) KRU 1Y-04 MID REPORT 1Y - 04 Single Completion Injector Conoco Phillips Alaska, Inc. Company: Conoco Phillips Alaska, Inc. Country: USA K Field: Kuparuk Logging Date: 25 – Oct - 2014 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 2 of 50 DATA RECORDED BY Dale Cain ANALYST Alfiia Gabdrakhmanova REVIEWED BY Matthew Lawrence Interpretations made by TGT OILFIELD SERVICES at the request of ConocoPhillips are based on information provided to TGT OILFIELD SERVICES by ConocoPhillips. All conclusions and recommendations were produced using measurements and empirical relationships and assumptions. All representations and warrant ies, expressed or implied, in respect of this report are hereby excluded. TGT OILFIELD SERVICES cannot, except in the case of negligence on part of TGT OILFIELD SERVICES, be held liable or responsible for any losses, costs, damages or expenses which might be incurred by anyone in relation to the contents of this report. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 3 of 50 CONTENTS 3 4 5 6 7 8 9 10 21 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 49 50 CONTENTS EXECUTIVE SUMMARY Fig. 1 Tubing Joint #75 – Tubing Corrosion with 31% of Metal Loss Fig. 2 Tubing Joint #113 – Tubing Corrosion with 28% of Metal Loss Fig. 3 Tubing Joint #80 – Tubing Corrosion with 26% of Metal Loss Fig. 4 Tubing Joint #155 – Tubing Corrosion with 25% of Metal Loss Fig. 5 Casing Joint #90 – Casing Corrosion with 17% of Metal Loss Fig. 6 Casing Joint #146 – Casing Corrosion with 17% of Metal Loss SURVEY RESULTS Fig. 7 Magnetic Imaging Defectoscope within Interval 20 – 300 ft Fig. 8 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Fig. 9 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Fig. 10 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Fig. 11Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Fig. 12 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Fig. 13 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Fig. 14 Magnetic Imaging Defectoscope within Interval 2,100 – 2,254 ft Fig. 15 Magnetic Imaging Defectoscope within Interval 2,254 – 2,500 ft Fig. 16 Magnetic Imaging Defectoscope within Interval 2,500 – 2,800 ft Fig. 17 Magnetic Imaging Defectoscope within Interval 2,800 – 3,100 ft Fig. 18 Magnetic Imaging Defectoscope within Interval 3,100 – 3,400 ft Fig. 19 Magnetic Imaging Defectoscope within Interval 3,400 – 3,700 ft Fig. 20 Magnetic Imaging Defectoscope within Interval 3,700 – 4,000 ft Fig. 21 Magnetic Imaging Defectoscope within Interval 4,000 – 4,300 ft Fig. 22 Magnetic Imaging Defectoscope within Interval 4,300 – 4,600 ft Fig. 23 Magnetic Imaging Defectoscope within Interval 4,600 – 4,900 ft Fig. 24 Magnetic Imaging Defectoscope within Interval 4,900 – 5,200 ft Fig. 25 Magnetic Imaging Defectoscope within Interval 5,190 – 5,500 ft Fig. 26 Magnetic Imaging Defectoscope within Interval 5,500 – 5,800 ft Fig. 27 Magnetic Imaging Defectoscope within Interval 6,000 – 6,300 ft Fig. 28 Magnetic Imaging Defectoscope within Interval 6,300 – 6,660 ft ATTACHMENTS SEQUENCE OF EVENTS WELL SCHEMATICS (Provided by Client) ABBREVIATIONS QUALITY CONTROL TGT MID LOGGING TOOL STRING SCHEMATIC DESCRIPTION OF LOGS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 4 of 50 EXECUTIVE SUMMARY OBJECTIVES To identify metal loss (corrosion) in the 3 1/2” tubing (first barrier) To identify metal loss (corrosion) in the 7” casing behind the 3 1/2” tubing – total metal content loss FINDINGS A Magnetic Imaging Defectoscope (MID) survey was run in 1Y-04 to identify the metal loss* in the 3 1/2” tubing and in the 7” casing behind the 3 1/2” tubing. MID data indicates the 3 1/2” tubing and 7” casing appear to range from good to poor condition. Metal loss* from 6% to 31% is recorded in the tubing and from 8% to 17% in the casing. Alternating amplitude increase and decrease responses (pictured as dark orange or blue spots in the near and far delta panels) without corresponding fluctuations on the respective tubing or casing thickness curve reflect tubing and/or casing eccentricity and/or deformation. 3 1/2” TUBING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Max. Metal Loss Depth (ft) What page in this report? Tabulation Log Plot 75 31 2371 13 5 113 28 3572 14 6 80 26 2545.5 13 7 155 25 4886 15 8 7” CASING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Max. Metal Loss Depth (ft) What page in this report? Tabulation Log Plot 90 17 3480.5 18 9 146 17 5674.9 19 10 * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for the tubing and 13 in. for the casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 5 of 50 Fig. 1 Tubing Joint #75 – Tubing Corrosion with 31% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collar Tubing corrosion with 31% metal loss Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 6 of 50 Fig. 2 Tubing Joint #113 – Tubing Corrosion with 28% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 28% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 7 of 50 Fig. 3 Tubing Joint #80 – Tubing Corrosion with 26% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 26% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 8 of 50 Fig. 4 Tubing Joint #155 – Tubing Corrosion with 25% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 25% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 9 of 50 Fig. 5 Casing Joint #90 – Casing Corrosion with 17% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Casing corrosion with 17% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 10 of 50 Fig. 6 Casing Joint #146 – Casing Corrosion with 17% of Metal Loss Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Casing corrosion with 17% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 11 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 1.1 0.0 30.5 N/A 1.2 30.5 38.0 2.1 38.0 67.5 corroded 64 7 2.2 67.5 75.5 2.3 75.5 85.5 2.4 85.5 95.7 3 95.7 126.0 4 126.0 157.4 corroded 141.5 7 5 157.4 187.4 6 187.4 218.9 corroded 204 11 7 218.9 250.8 corroded 235.5 11 245.5 13 8 250.8 282.2 9 282.2 312.9 corroded 304 20 10 312.9 344.6 corroded 320 8 11 344.6 375.8 12 375.8 407.5 13 407.5 438.4 corroded 417.5 11 14 438.4 469.4 corroded 460.5 10 466 9 15 469.4 501.0 corroded 491.5 9 16 501.0 532.0 17 532.0 563.0 18 563.0 594.6 corroded 566.5 17 572.5 11 19 594.6 626.5 corroded 598.5 12 604.8 7 618 10 20 626.5 658.0 21 658.0 689.4 corroded 662 11 22 689.4 721.1 23 721.1 751.8 corroded 726 19 738.5 8 24 751.8 783.2 25 783.2 814.4 corroded 787 10 793 10 26 814.4 845.9 corroded 836 21 27 845.9 877.5 28 877.5 908.2 corroded 880.9 8 887.5 15 29 908.2 939.9 corroded 910 9 914 6 30 939.9 971.6 corroded 949.5 20 962.5 8 31 971.6 1002.5 corroded 979.5 10 32 1002.5 1034.0 33 1034.0 1065.4 corroded 1037.5 20 1043 11 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 12 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 34 1065.4 1096.4 corroded 1075 12 1087 8 35 1096.4 1127.1 corroded 1099.5 10 1105.5 13 36 1127.1 1157.8 corroded 1128.5 15 1141.5 15 1153.5 10 37 1157.8 1189.0 38 1189.0 1220.5 corroded 1194.6 8 39 1220.5 1251.0 corroded 1227.5 16 1241 8 40 1251.0 1282.4 41 1282.4 1313.8 corroded 1299 7 42 1313.8 1344.1 corroded 1323 6 43 1344.1 1374.1 corroded 1354.5 10 44 1374.1 1405.5 corroded 1384 19 1397.5 14 45 1405.5 1437.4 1427 19 1433 18 46 1437.4 1469.1 1444.5 10 47 1469.1 1500.1 1479 6 1497 10 48 1500.1 1531.5 49 1531.5 1562.9 corroded 1554 8 50 1562.9 1594.6 corroded 1566 10 51 1594.6 1626.0 corroded 1598.5 17 52 1626.0 1657.2 corroded 1631 10 53 1657.2 1688.4 54 1688.4 1718.5 corroded 1696 7 1709 20 1717 11 55 1718.5 1748.3 56 1748.3 1779.0 corroded 1758.5 10 57.1 1779.0 1810.4 57.2 1810.4 1830.0 58 1830.0 1860.9 59 1860.9 1891.4 corroded 1869.1 7 60 1891.4 1921.5 61 1921.5 1952.7 corroded 1928.5 20 62 1952.7 1984.1 63 1984.1 2015.8 corroded 1997 8 64 2015.8 2047.0 corroded 2044.5 18 65 2047.0 2078.4 66 2078.4 2110.1 corroded 2106.5 20 67 2110.1 2142.0 68 2142.0 2173.6 69 2173.6 2204.5 corroded 2196 10 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 13 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 70 2204.5 2236.2 corroded 2209.5 8 71 2236.2 2267.9 72 2267.9 2299.1 corroded 2271 10 2277 10 73 2299.1 2329.4 corroded 2304.5 10 74 2329.4 2360.8 corroded 2351 12 75 2360.8 2392.5 corroded 2371 31 76 2392.5 2423.2 corroded 2407.5 14 77 2423.2 2454.9 78 2454.9 2485.8 corroded 2459 20 2471.2 17 2481.5 10 79.1 2485.8 2516.6 79.2 2516.6 2526.3 80 2526.3 2553.8 corroded 2545.5 26 81 2553.8 2585.5 corroded 2568.5 15 2581.5 13 82 2585.5 2617.1 corroded 2613 10 83 2617.1 2647.4 corroded 2638.9 17 84 2647.4 2677.9 corroded 2656.3 10 2669 20 85 2677.9 2707.7 86 2707.7 2737.3 corroded 2717 8 2730 11 87 2737.3 2768.5 88 2768.5 2799.9 corroded 2785 8 89 2799.9 2831.6 corroded 2822 12 90 2831.6 2862.8 91 2862.8 2893.5 corroded 2890.5 16 92 2893.5 2923.5 93 2923.5 2953.1 corroded 2932.5 9 2944.6 10 2947 9 94 2953.1 2982.4 corroded 2959.3 9 95 2982.4 3013.9 corroded 2987.1 10 96 3013.9 3045.0 97 3045.0 3076.5 corroded 3067.5 15 3074.5 20 98 3076.5 3107.0 99 3107.0 3139.1 100 3139.1 3170.3 corroded 3140.5 21 3144 14 3163.5 9 3167 12 101 3170.3 3202.4 102 3202.4 3236.0 corroded 3205.5 9 3233.8 19 103 3236.0 3266.0 corroded 3262.5 13 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 14 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 104 3266.0 3297.2 105 3297.2 3329.1 106 3329.1 3360.0 corroded 3353 10 107 3360.0 3391.2 corroded 3369.5 15 108 3391.2 3422.7 corroded 3413.5 16 109 3422.7 3454.1 110 3454.1 3485.5 corroded 3481 11 111 3485.5 3517.0 112 3517.0 3548.4 corroded 3526.5 10 113 3548.4 3580.3 corroded 3559 24 3572 28 3578 13 114 3580.3 3611.5 115.1 3611.5 3643.1 115.2 3643.1 3652.7 116 3652.7 3681.3 117 3681.3 3712.5 corroded 3690.5 19 118 3712.5 3744.2 119 3744.2 3774.9 120 3774.9 3806.4 corroded 3784 19 121 3806.4 3836.6 122 3836.6 3868.5 corroded 3845.5 19 3858.5 18 123 3868.5 3900.0 124 3900.0 3931.4 125 3931.4 3962.6 126 3962.6 3993.3 corroded 3971.5 10 127 3993.3 4024.0 128 4024.0 4056.2 129 4056.2 4088.1 corroded 4073 23 130.1 4088.1 4118.6 130.2 4118.6 4125.6 131 4125.6 4156.5 corroded 4128.5 10 4130.5 10 132 4156.5 4187.7 133 4187.7 4218.4 134 4218.4 4250.6 135 4250.6 4282.5 136 4282.5 4313.5 corroded 4291.5 16 137 4313.5 4343.5 corroded 4329 10 138 4343.5 4375.6 corroded 4353.5 16 139 4375.6 4405.2 140 4405.2 4437.5 141 4437.5 4469.0 142 4469.0 4500.4 143 4500.4 4531.8 144 4531.8 4561.4 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 15 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 145.1 4561.4 4590.9 145.2 4590.9 4601.5 146 4601.5 4628.7 147 4628.7 4660.1 148 4660.1 4691.5 149 4691.5 4724.5 corroded 4696.4 10 4709.5 10 150 4724.5 4755.6 corroded 4751.5 10 151 4755.6 4784.9 152 4784.9 4817.0 153 4817.0 4848.5 154 4848.5 4878.0 155 4878.0 4907.1 corroded 4886 25 156 4907.1 4938.5 corroded 4933 10 157 4938.5 4968.4 158 4968.4 5002.1 159 5002.1 5033.5 160.1 5033.5 5065.7 160.2 5065.7 5074.8 161 5074.8 5103.4 162 5103.4 5135.0 163 5135.0 5166.2 164 5166.2 5198.2 165 5198.2 5230.5 corroded 5201 22 166 5230.5 5261.0 167 5261.0 5292.5 168 5292.5 5322.5 169 5322.5 5353.9 corroded 5327 15 170 5353.9 5385.6 corroded 5358 17 5364 13 171 5385.6 5417.0 172 5417.0 5448.4 173 5448.4 5479.2 174 5479.2 5509.9 175.1 5509.9 5539.9 175.2 5539.9 5547.0 176 5547.0 5578.6 177 5578.6 5609.3 corroded 5588 9 178 5609.3 5640.7 179 5640.7 5671.0 corroded 5663.5 10 180 5671.0 5702.4 181 5702.4 5734.1 182 5734.1 5765.1 183 5765.1 5797.7 184 5797.7 5828.8 185 5828.8 5858.7 186 5858.7 5891.0 187 5891.0 5922.2 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 16 of 50 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 188 5922.2 5953.9 189.1 5953.9 5985.1 189.2 5985.1 5992.5 190 5992.5 6022.3 191 6022.3 6054.2 192 6054.2 6084.7 193 6084.7 6116.1 194 6116.1 6147.6 195 6147.6 6178.5 196 6178.5 6210.0 197 6210.0 6242.1 corroded 6220.5 10 198 6242.1 6273.8 199 6273.8 6305.0 200 6305.0 6335.9 corroded 6327 14 201 6335.9 6367.6 202.1 6367.6 6398.3 202.2 6398.3 6405.0 203 6405.0 6435.8 204 6435.8 6467.2 205 6467.2 6497.3 206 6497.3 6528.7 corroded 6519.6 11 6525 9 207 6528.7 6559.4 208.1 6559.4 6590.6 208.2 6590.6 6602.5 209 6602.5 6633.0 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 17 of 50 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 1 0.0 41.0 2 41.0 79.9 3 79.9 114.8 4 114.8 154.4 5 154.4 192.6 6 192.6 231.4 7 231.4 269.4 8 269.4 306.9 9 306.9 343.9 10 343.9 382.8 11 382.8 422.4 12 422.4 459.6 13 459.6 497.6 14 497.6 536.9 15 536.9 576.0 16 576.0 616.1 17 616.1 655.2 18 655.2 694.5 19 694.5 734.3 20 734.3 773.7 21 773.7 811.6 22 811.6 851.4 23 851.4 888.2 24 888.2 926.2 25 926.2 965.5 26 965.5 1005.6 27 1005.6 1044.7 28 1044.7 1084.0 29 1084.0 1123.1 30 1123.1 1162.3 31 1162.3 1202.1 32 1202.1 1240.9 33 1240.9 1280.3 34 1280.3 1319.9 35 1319.9 1359.4 36 1359.4 1399.3 37 1399.3 1439.1 38 1439.1 1478.2 39 1478.2 1517.5 40 1517.5 1556.9 41 1556.9 1596.7 42 1596.7 1633.2 43 1633.2 1673.1 44 1673.1 1712.4 45 1712.4 1752.0 46 1752.0 1791.6 47 1791.6 1830.0 48 1830.0 1868.4 49 1868.4 1908.2 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 18 of 50 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 50 1908.2 1944.8 51 1944.8 1985.0 52 1985.0 2022.5 53 2022.5 2061.4 54 2061.4 2101.4 55 2101.4 2142.0 56 2142.0 2177.3 57 2177.3 2214.1 58 2214.1 2253.7 59 2253.7 2291.4 60 2291.4 2331.5 corroded 2304.7 8 61 2331.5 2369.9 62 2369.9 2409.7 63 2409.7 2449.3 64 2449.3 2488.6 65 2488.6 2526.3 66 2526.3 2565.9 67 2565.9 2605.3 68 2605.3 2644.8 69 2644.8 2684.4 corroded 2674 8 70 2684.4 2724.0 71 2724.0 2762.6 72 2762.6 2802.5 73 2802.5 2842.0 74 2842.0 2882.1 75 2882.1 2921.0 76 2921.0 2961.2 77 2961.2 3001.0 78 3001.0 3040.9 79 3040.9 3080.4 80 3080.4 3120.2 81 3120.2 3159.4 82 3159.4 3199.2 83 3199.2 3239.7 84 3239.7 3277.4 85 3277.4 3317.0 86 3317.0 3356.8 87 3356.8 3396.6 88 3396.6 3436.2 89 3436.2 3473.2 corroded 3426.6 10 90 3473.2 3513.0 corroded 3480.5 17 91 3513.0 3551.9 92 3551.9 3591.5 93 3591.5 3631.5 94 3631.5 3670.2 95 3670.2 3709.7 96 3709.7 3748.9 97 3748.9 3788.5 98 3788.5 3825.7 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 19 of 50 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 99 3825.7 3863.2 100 3863.2 3903.0 101 3903.0 3942.3 102 3942.3 3979.1 103 3979.1 4018.5 104 4018.5 4058.5 105 4058.5 4097.1 106 4097.1 4136.7 corroded 4116.1 10 106 4129 10 107 4136.7 4176.1 108 4176.1 4214.5 109 4214.5 4255.0 110 4255.0 4293.7 111 4293.7 4333.5 112 4333.5 4373.0 113 4373.0 4411.5 114 4411.5 4451.5 115 4451.5 4487.8 116 4487.8 4526.9 117 4526.9 4565.5 118 4565.5 4604.2 119 4604.2 4644.0 120 4644.0 4683.4 121 4683.4 4724.5 122 4724.5 4762.8 123 4762.8 4802.8 124 4802.8 4839.4 125 4839.4 4879.5 126 4879.5 4917.6 127 4917.6 4954.2 128 4954.2 4995.1 129 4995.1 5034.3 130 5034.3 5071.9 131 5071.9 5111.3 132 5111.3 5151.3 133 5151.3 5189.8 corroded 5170.5 10 134 5189.8 5227.0 135 5227.0 5266.8 136 5266.8 5306.2 137 5306.2 5346.0 138 5346.0 5383.2 139 5383.2 5423.1 140 5423.1 5462.6 141 5462.6 5502.2 142 5502.2 5541.6 143 5541.6 5580.7 144 5580.7 5618.4 corroded 5582.5 11 145 5618.4 5655.9 146 5655.9 5692.7 corroded 5674.9 17 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 20 of 50 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 147 5692.7 5732.5 148 5732.5 5772.0 corroded 5760.5 9 149 5772.0 5811.8 150 5811.8 5850.5 151 5850.5 5887.8 152 5887.8 5927.1 153 5927.1 5966.4 154 5966.4 6002.8 155 6002.8 6039.3 156 6039.3 6079.1 157 6079.1 6118.9 158 6118.9 6155.2 159 6155.2 6195.1 160 6195.1 6232.1 161 6232.1 6270.7 162 6270.7 6308.2 163 6308.2 6347.8 164 6347.8 6387.1 165 6387.1 6426.5 166 6426.5 6466.8 corroded 6464.5 10 167 6466.8 6505.4 168 6505.4 6544.5 169 6544.5 6584.1 170 6584.1 6621.4 Note: According to MID survey 10 3/4" casing shoe was detected at 2254 ft. * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for tubing and 13 in. for casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 21 of 50 SURVEY RESULTS Fig. 7 Magnetic Imaging Defectoscope within Interval 20 – 300 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collars Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 22 of 50 Fig. 8 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 23 of 50 Fig. 9 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 24 of 50 Fig. 10 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 25 of 50 Fig. 11Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 26 of 50 Fig. 12 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 27 of 50 Fig. 13 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 28 of 50 Fig. 14 Magnetic Imaging Defectoscope within Interval 2,100 – 2,254 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 29 of 50 Fig. 15 Magnetic Imaging Defectoscope within Interval 2,254 – 2,500 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 30 of 50 Fig. 16 Magnetic Imaging Defectoscope within Interval 2,500 – 2,800 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 31 of 50 Fig. 17 Magnetic Imaging Defectoscope within Interval 2,800 – 3,100 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 32 of 50 Fig. 18 Magnetic Imaging Defectoscope within Interval 3,100 – 3,400 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 33 of 50 Fig. 19 Magnetic Imaging Defectoscope within Interval 3,400 – 3,700 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 34 of 50 Fig. 20 Magnetic Imaging Defectoscope within Interval 3,700 – 4,000 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 35 of 50 Fig. 21 Magnetic Imaging Defectoscope within Interval 4,000 – 4,300 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 36 of 50 Fig. 22 Magnetic Imaging Defectoscope within Interval 4,300 – 4,600 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 37 of 50 Fig. 23 Magnetic Imaging Defectoscope within Interval 4,600 – 4,900 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 38 of 50 Fig. 24 Magnetic Imaging Defectoscope within Interval 4,900 – 5,200 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 39 of 50 Fig. 25 Magnetic Imaging Defectoscope within Interval 5,190 – 5,500 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 40 of 50 Fig. 26 Magnetic Imaging Defectoscope within Interval 5,500 – 5,800 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 41 of 50 Fig. 27 Magnetic Imaging Defectoscope within Interval 6,000 – 6,300 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 42 of 50 Fig. 28 Magnetic Imaging Defectoscope within Interval 6,300 – 6,660 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” Tubing thickness 7” Casing thickness 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 43 of 50 ATTACHMENTS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 44 of 50 ATTACHMENT 1 SEQUENCE OF EVENTS Well 1Y-04 Completion Single Completion Injector Oil field Kuparuk Date 2014/10/25 State Well is shut-in Survey MID survey The MID (Magnetic Imaging Defectoscope) was recorded with TGT memory tools by PDS on an HLS-760 unit. Date Time Start of interval, ft End of Interval, ft Logging speed, ft/min Las Name Event 2 5 -Oc t -14 MID Survey 05:30 Travel. 06:40 Arrive on location. 06:50 Safety meeting. 07:44 Program tool. 08:00 Standby - right angle drive broke - HLS goes to get one. 09:00 End standby. 09:04 Stab on Lubricator - Run 1. 09:14 0 6650 150 RIH. 09:59 At 6620' slickline measured depth - 36' KB. 10:04 6650 0 16 S5U1 Start log out of hole. 12:07 Line oiler froze up. Line jerking badly. At ~4900' cable speed was increased up to 50'/min for a few minutes. 12:44 Standby - wireline frose up. Wait on hot oil truck at 4365'. 14:53 End Standby. LRS pumped fluid. Start the logging again. 07:35 At surface. 19:40 dnln dtr 19:57 Break Off Lubricator - Run 1. 20:20 dnld mem 20:40 Travel 21:00 End Ticket Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 45 of 50 ATTACHMENT 2 WELL SCHEMATICS (Provided by Client) Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 46 of 50 ATTACHMENT 3 ABBREVIATIONS Nomenclature Description G/C Gauge cutter MID Magnetic imaging defectoscope HPT High precision temperature HUD Hold up depth POOH Pull out of hole R/D Rig down R/U Rig up RIH Run in hole RU Reservoir unit THP Tubing head pressure Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 47 of 50 ATTACHMENT 4 QUALITY CONTROL Logging speed while MID runs was 16±2 ft/min. Depth was correlated using well sketch provided by ConocoPhillips. 3 1/2" tubing thickness 7” casing thickness SSSV Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 48 of 50 SBR 3 1/2" tubing thickness 7” casing thickness GL Mandrel Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 49 of 50 ATTACHMENT 5 TGT MID LOGGING TOOL STRING SCHEMATIC Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Page 50 of 50 ATTACHMENT 6 DESCRIPTION OF LOGS Original logs A list of recorded logs is given below. Calculated profiles A list of all profiles derived from original logs is given below. LOG UNIT DESCRIPTION COMMENTS DEPTH ft Measured depth Calculated from RKB LSPD ft/min Cable speed SS RESPONSE mV Short sensor response 42 points of time response (0.1-75 ms) LS RESPONSE mV Long sensor response 51 points of time response (0.1-275 ms) LOG UNIT DESCRIPTION COMMENTS Thickness 1 inch 3 1/2” tubing thickness Thickness 2 inch 7” casing thickness NEAR DELTA V/V Near Zone Model Deviation 40 points of time response (0.133-56.2 ms) FAR DELTA V/V Far Zone Model Deviation 34 points of time response (2.37-274 ms) MID REPORT 1 Y -04 Single Completion Injector ConocoPhillips Alaska, Inc. Company: ConocoPhillips Alaska, Inc. Country: USA K Field: Kuparuk Logging Date: 25 – Oct – 2014 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing DATA RECORDED BY Dale Cain ANALYST Alfiia Gabdrakhmanova REVIEWED BY Matthew Lawrence Interpretations made by TGT OILFIELD SERVICES at the request of ConocoPhillips are based on information provided to TGT OILFIELD SERVICES by ConocoPhillips. All conclusions and recommendations were produced using measurements and empirical relationships and assumptions. All representations and warranties, expressed or implied, in respect of this report are hereby excluded. TGT OILFIELD SERVICES cannot, except in the case of negligence on part of TGT OILFIELD SERVICES, be held liable or responsible for any losses, costs, damages or expenses which might be incurred by anyone in relation to the contents of this report. Page 2 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing CONTENTS 3 4 15 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 43 44 CONTENTS EXECUTIVE SUMMARY SURVEY RESULTS Fig. 1 Magnetic Imaging Defectoscope Fig. 2 Magnetic Imaging Defectoscope Fig. 3 Magnetic Imaging Defectoscope Fig. 4 Magnetic Imaging Defectoscope ctoscope Fig. 6 Magnetic Imaging Defectoscope Fig. 7 Magnetic Imaging Defectoscope Fig. 8 Magnetic Imaging Defectoscope Fig. 9 Magnetic Imaging Defectoscope ging Defectoscope Fig. 11 Magnetic Imaging Defectoscope Fig. 12 Magnetic Imaging Defectoscope Fig. 13 Magnetic Imaging Defectoscope Fig. 14 Magnetic Imaging Defectoscope Magnetic Imaging Defectoscope Fig. 16 Magnetic Imaging Defectoscope Fig. 17 Magnetic Imaging Defectoscope Fig. 18 Magnetic Imaging Defectoscope Fig. 19 Magnetic Imaging Defectoscope Fig. 20 Magnetic Imaging Defectoscope Fig. 21 Magnetic Imaging Defectoscope Fig. 22 Magnetic Imaging Defectoscope within Interval 20 – 300 ft within Interval 300 – 600 ft within Interval 600 – 900 ft within Interval 900 – 1,200 ft Fig. 5 Magnetic Imaging Defe within Interval 1,200 – 1,500 ft within Interval 1,500 – 1,800 ft within Interval 1,800 – 2,100 ft within Interval 2,100 – 2,400 ft within Interval 2,400 – 2,700 ft Fig. 10 Magnetic Ima within Interval 2,700 – 3,000 ft within Interval 3,000 – 3,300 ft within Interval 3,300 – 3,600 ft within Interval 3,600 – 3,900 ft within Interval 3,900 – 4,200 ft Fig. 15 within Interval 4,200 – 4,500 ft within Interval 4,500 – 4,800 ft within Interval 4,800 – 5,100 ft within Interval 5,100 – 5,400 ft within Interval 5,400 – 5,700 ft within Interval 5,700 – 6,000 ft within Interval 6,000 – 6,300 ft within Interval 6,300 – 6,660 ft ATTACHMENTS SEQUENCE OF EVENTS WELL SCHEMATICS (Provided by Client) ABBREVIATIONS QUALITY CONTROL TGT MID LOGGING TOOL STRING SCHEMATIC DESCRIPTION OF LOGS Page 3 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing EXECUTIVE SUMMARY OBJECTIVES To identify metal loss (corrosion) in the 3 1/2” tubing (first barrier) To identify metal loss (corrosion) in the 7” casing behind the 3 1/2” tubing – total metal content loss FINDINGS A Magnetic Imaging Defectoscope (MID) survey was run in 1Y-04 to identify the metal loss* in the 3 1/2” tubing and in the 7” casing behind the 3 1/2” tubing. MID data indicates the 3 1/2” tubing and 7” casing appear to range from good to poor condition. Metal loss* from 6% to 31% is recorded in the tubing and from 8% to 17% in the casing. Alternating amplitude increase and decrease responses (pictured as dark orange or blue spots in the near and far delta panels) without corresponding fluctuations on the respective tubing or casing thickness curve reflect tubing and/or casing eccentricity and/or deformation. 3 1/2” TUBING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Depth Interval of Metal Loss (ft) What page in this report? Tabulation Log Plot 80 31 2370 2372.5 7 22 119 28 3571.5 3573.5 8 26 86 26 2545 2547.5 7 23 164 25 4885 4889 9 31 7” CASING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Depth Interval of Metal Loss (ft) What page in this report? Tabulation Log Plot 146 17 5673 5677 14 33 90 17 3479.5 3481.5 12 26 * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for the tubing and 13 in. for the casing. Page 4 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) First Barrier: 3.5” Tubing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 1 0.0 30.5 N/A 2 30.5 38.0 good 3 38.0 67.5 corroded 63-64.5 7 4 67.5 75.5 good 5 75.5 85.5 good 6 85.5 95.7 good 7 95.7 126.0 good 8 126.0 157.4 corroded 140.5-142 7 9 157.4 187.4 good 10 187.4 218.9 corroded 203-204.5 11 11 218.9 250.8 corroded 235-236.5 11 244.5-247.5 13 12 250.8 282.2 good 13 282.2 312.9 corroded 303-305 20 14 312.9 344.6 corroded 320-320.5 8 15 344.6 375.8 good 16 375.8 407.5 good 17 407.5 438.4 corroded 416.5-418 11 18 438.4 469.4 corroded 460-461 10 465-467 9 19 469.4 501.0 corroded 491-492 9 20 501.0 532.0 good 21 532.0 563.0 good 22 563.0 594.6 corroded 566-567 17 571.5-573.5 11 23 594.6 626.5 corroded 598-599.5 12 604.5-605.5 7 617.5-618.5 10 24 626.5 658.0 good 25 658.0 689.4 corroded 661.5-662.5 11 26 689.4 721.1 good 27 721.1 751.8 corroded 725.5-727 19 738-739 8 28 751.8 783.2 good 29 783.2 814.4 corroded 786.5-787.5 10 791.5-794 10 30 814.4 845.9 corroded 835.5-837 21 31 845.9 877.5 good 32 877.5 908.2 corroded 880-881.5 8 886-888 15 33 908.2 939.9 corroded 910-911 9 914-914.5 6 34 939.9 971.6 corroded 949-950.5 20 962-963 8 35 971.6 1002.5 corroded 979-980.5 10 36 1002.5 1034.0 good 37 1034.0 1065.4 corroded 1037-1039 20 37 1042.5-1045 11 Page 5 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) First Barrier: 3.5” Tubing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 38 1065.4 1096.4 corroded 1074-1076 12 1086.5-1088 8 39 1096.4 1127.1 corroded 1099-1100.5 10 1104.5-1106 13 40 1127.1 1157.8 corroded 1128-1132 15 1140-1142.5 15 1152-1154.5 10 41 1157.8 1189.0 good 42 1189.0 1220.5 corroded 1192.5-1196 8 43 1220.5 1251.0 corroded 1225-1228.5 16 1240.5-1242 8 44 1251.0 1282.4 good 45 1282.4 1313.8 corroded 1299-1299.5 7 46 1313.8 1344.1 corroded 1322-1323 6 47 1344.1 1374.1 corroded 1353.5-1355 10 48 1374.1 1405.5 corroded 1383-1385 19 1397-1398 14 49 1405.5 1437.4 1426-1428 19 1431.5-1433.5 18 50 1437.4 1469.1 1443.5-1447 10 51 1469.1 1500.1 1478-1479 6 1495.5-1497.5 10 52 1500.1 1531.5 good 53 1531.5 1562.9 corroded 1553-1554.5 8 54 1562.9 1594.6 corroded 1565.5-1567.5 10 55 1594.6 1626.0 corroded 1598-1599 17 56 1626.0 1657.2 corroded 1630-1632 10 57 1657.2 1688.4 good 58 1688.4 1718.5 corroded 1696-1698 7 1708-1710.5 20 1716.5-1717.5 11 59 1718.5 1748.3 good 60 1748.3 1779.0 corroded 1756-1759 10 61 1779.0 1810.4 good 62 1810.4 1830.0 good 63 1830.0 1860.9 good 64 1860.9 1891.4 corroded 1868.5-1870 7 65 1891.4 1921.5 good 66 1921.5 1952.7 corroded 1927-1930.5 20 67 1952.7 1984.1 good 68 1984.1 2015.8 corroded 1996.5-1997.5 8 69 2015.8 2047.0 corroded 2043-2046 18 70 2047.0 2078.4 good 71 2078.4 2110.1 corroded 2105-2108 20 72 2110.1 2142.0 good 73 2142.0 2173.6 good 74 2173.6 2204.5 corroded 2195-2197 10 Page 6 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) First Barrier: 3.5” Tubing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 75 2204.5 2236.2 corroded 2209-2210 8 76 2236.2 2267.9 good 77 2267.9 2299.1 corroded 2271-2272 10 2276-2278 10 78 2299.1 2329.4 corroded 2304-2305 10 79 2329.4 2360.8 corroded 2350-2351.5 12 80 2360.8 2392.5 corroded 2370-2372.5 31 81 2392.5 2423.2 corroded 2406.5-2408 14 82 2423.2 2454.9 good 83 2454.9 2485.8 corroded 2458-2460.5 20 2470-2472 17 2480-2484 10 84 2485.8 2516.6 good 85 2516.6 2526.3 good 86 2526.3 2553.8 corroded 2545-2547.5 26 87 2553.8 2585.5 corroded 2568-2569.5 15 2581-2583 13 88 2585.5 2617.1 corroded 2612.5-2614 10 89 2617.1 2647.4 corroded 2637.5-2640 17 90 2647.4 2677.9 corroded 2656-2657 10 2668-2670 20 91 2677.9 2707.7 good 92 2707.7 2737.3 corroded 2716.5-2718.5 8 2729.5-2732 11 93 2737.3 2768.5 good 94 2768.5 2799.9 corroded 2784-2786 8 95 2799.9 2831.6 corroded 2821.5-2823 12 96 2831.6 2862.8 good 97 2862.8 2893.5 corroded 2889-2892 16 98 2893.5 2923.5 good 99 2923.5 2953.1 corroded 2932-2933 9 2944-2945.5 10 2946.5-2948 9 100 2953.1 2982.4 corroded 2958.5-2960 9 101 2982.4 3013.9 corroded 2985-2987.5 10 102 3013.9 3045.0 good 103 3045.0 3076.5 corroded 3066.5-3068 15 3073-3075 20 104 3076.5 3107.0 good 105 3107.0 3139.1 good 106 3139.1 3170.3 corroded 3140-3141 21 3143.5-3145 14 3163-3164 9 3166.5-3169 12 107 3170.3 3202.4 good 108 3202.4 3236.0 corroded 3204-3206 9 108 3233-3235 19 109 3236.0 3266.0 corroded 3262-3263 13 Page 7 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) First Barrier: 3.5” Tubing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 110 3266.0 3297.2 good 111 3297.2 3329.1 good 112 3329.1 3360.0 corroded 3353-3354 10 113 3360.0 3391.2 corroded 3368.5-3370 15 114 3391.2 3422.7 corroded 3413-3414.5 16 115 3422.7 3454.1 good 116 3454.1 3485.5 corroded 3480-3481.5 11 117 3485.5 3517.0 good 118 3517.0 3548.4 corroded 3526-3527 10 119 3548.4 3580.3 corroded 3558-3559.5 24 3571.5-3573.5 28 3577.5-3579 13 120 3580.3 3611.5 good 121 3611.5 3643.1 good 122 3643.1 3652.7 good 123 3652.7 3681.3 good 124 3681.3 3712.5 corroded 3690-3691 19 125 3712.5 3744.2 good 126 3744.2 3774.9 good 127 3774.9 3806.4 corroded 3783.5-3785.5 19 128 3806.4 3836.6 good 129 3836.6 3868.5 corroded 3845-3846 19 3858-3859.5 18 130 3868.5 3900.0 good 131 3900.0 3931.4 good 132 3931.4 3962.6 good 133 3962.6 3993.3 corroded 3971-3974 10 134 3993.3 4024.0 good 135 4024.0 4056.2 good 136 4056.2 4088.1 corroded 4071.5-4074 23 137 4088.1 4118.6 good 138 4118.6 4125.6 good 139 4125.6 4156.5 corroded 4128-4129 10 4130.5-4131.5 10 140 4156.5 4187.7 good 141 4187.7 4218.4 good 142 4218.4 4250.6 good 143 4250.6 4282.5 good 144 4282.5 4313.5 corroded 4290-4292 16 145 4313.5 4343.5 corroded 4329-4330 10 146 4343.5 4375.6 corroded 4353-4354 16 147 4375.6 4405.2 good 148 4405.2 4437.5 good 149 4437.5 4469.0 good 150 4469.0 4500.4 good 151 4500.4 4531.8 good 152 4531.8 4561.4 good Page 8 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 153 4561.4 4590.9 good 154 4590.9 4601.5 good 155 4601.5 4628.7 good 156 4628.7 4660.1 good 157 4660.1 4691.5 good 158 4691.5 4724.5 corroded 4695-4697 10 4708-4711 10 159 4724.5 4755.6 corroded 4750.5-4752 10 160 4755.6 4784.9 good 161 4784.9 4817.0 good 162 4817.0 4848.5 good 163 4848.5 4878.0 good 164 4878.0 4907.1 corroded 4885-4889 25 165 4907.1 4938.5 corroded 4931.5-4934 10 166 4938.5 4968.4 good 167 4968.4 5002.1 good 168 5002.1 5033.5 good 169 5033.5 5065.7 good 170 5065.7 5074.8 good 171 5074.8 5103.4 good 172 5103.4 5135.0 good 173 5135.0 5166.2 good 174 5166.2 5198.2 good 175 5198.2 5230.5 corroded 5200-5202 22 176 5230.5 5261.0 good 177 5261.0 5292.5 good 178 5292.5 5322.5 good 179 5322.5 5353.9 corroded 5326-5327.5 15 180 5353.9 5385.6 corroded 5357-5358.5 17 5363.5-5365 13 181 5385.6 5417.0 good 182 5417.0 5448.4 good 183 5448.4 5479.2 good 184 5479.2 5509.9 good 185 5509.9 5539.9 good 186 5539.9 5547.0 good 187 5547.0 5578.6 good 188 5578.6 5609.3 corroded 5588-5589 9 189 5609.3 5640.7 good 190 5640.7 5671.0 corroded 5662-5663.5 10 191 5671.0 5702.4 good 192 5702.4 5734.1 good 193 5734.1 5765.1 good 194 5765.1 5797.7 good 195 5797.7 5828.8 good 196 5828.8 5858.7 good 197 5858.7 5891.0 good 198 5891.0 5922.2 good Page 9 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) First Barrier: 3.5” Tubing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 199 5922.2 5953.9 good 200 5953.9 5985.1 good 201 5985.1 5992.5 good 202 5992.5 6022.3 good 203 6022.3 6054.2 good 204 6054.2 6084.7 good 205 6084.7 6116.1 good 206 6116.1 6147.6 good 207 6147.6 6178.5 good 208 6178.5 6210.0 good 209 6210.0 6242.1 corroded 6219.5-6221 10 210 6242.1 6273.8 good 211 6273.8 6305.0 good 212 6305.0 6335.9 corroded 6326-6328 14 213 6335.9 6367.6 good 214 6367.6 6398.3 good 215 6398.3 6405.0 good 216 6405.0 6435.8 good 217 6435.8 6467.2 good 218 6467.2 6497.3 good 219 6497.3 6528.7 corroded 6519-6520 11 6525-6526 9 220 6528.7 6559.4 good 221 6559.4 6590.6 good 222 6590.6 6602.5 good 223 6602.5 6633.0 good Page 10 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) Second Barrier: 7” Casing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 1 0.0 41.0 good 2 41.0 79.9 good 3 79.9 114.8 good 4 114.8 154.4 good 5 154.4 192.6 good 6 192.6 231.4 good 7 231.4 269.4 good 8 269.4 306.9 good 9 306.9 343.9 good 10 343.9 382.8 good 11 382.8 422.4 good 12 422.4 459.6 good 13 459.6 497.6 good 14 497.6 536.9 good 15 536.9 576.0 good 16 576.0 616.1 good 17 616.1 655.2 good 18 655.2 694.5 good 19 694.5 734.3 good 20 734.3 773.7 good 21 773.7 811.6 good 22 811.6 851.4 good 23 851.4 888.2 good 24 888.2 926.2 good 25 926.2 965.5 good 26 965.5 1005.6 good 27 1005.6 1044.7 good 28 1044.7 1084.0 good 29 1084.0 1123.1 good 30 1123.1 1162.3 good 31 1162.3 1202.1 good 32 1202.1 1240.9 good 33 1240.9 1280.3 good 34 1280.3 1319.9 good 35 1319.9 1359.4 good 36 1359.4 1399.3 good 37 1399.3 1439.1 good 38 1439.1 1478.2 good 39 1478.2 1517.5 good 40 1517.5 1556.9 good 41 1556.9 1596.7 good 42 1596.7 1633.2 good 43 1633.2 1673.1 good 44 1673.1 1712.4 good 45 1712.4 1752.0 good 46 1752.0 1791.6 good 47 1791.6 1830.0 good 48 1830.0 1868.4 good 49 1868.4 1908.2 good Page 11 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) Second Barrier: 7” Casing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 50 1908.2 1944.8 good 51 1944.8 1985.0 good 52 1985.0 2022.5 good 53 2022.5 2061.4 good 54 2061.4 2101.4 good 55 2101.4 2142.0 good 56 2142.0 2177.3 good 57 2177.3 2214.1 good 58 2214.1 2253.7 good 59 2253.7 2291.4 good 60 2291.4 2331.5 corroded 2304-2305.5 8 61 2331.5 2369.9 good 62 2369.9 2409.7 good 63 2409.7 2449.3 good 64 2449.3 2488.6 good 65 2488.6 2526.3 good 66 2526.3 2565.9 good 67 2565.9 2605.3 good 68 2605.3 2644.8 good 69 2644.8 2684.4 corroded 2672-2675 8 70 2684.4 2724.0 good 71 2724.0 2762.6 good 72 2762.6 2802.5 good 73 2802.5 2842.0 good 74 2842.0 2882.1 good 75 2882.1 2921.0 good 76 2921.0 2961.2 good 77 2961.2 3001.0 good 78 3001.0 3040.9 good 79 3040.9 3080.4 good 80 3080.4 3120.2 good 81 3120.2 3159.4 good 82 3159.4 3199.2 good 83 3199.2 3239.7 good 84 3239.7 3277.4 good 85 3277.4 3317.0 good 86 3317.0 3356.8 good 87 3356.8 3396.6 good 88 3396.6 3436.2 good 89 3436.2 3473.2 corroded 3426-3428 10 90 3473.2 3513.0 corroded 3479.5-3481.5 17 91 3513.0 3551.9 good 92 3551.9 3591.5 good 93 3591.5 3631.5 good 94 3631.5 3670.2 good 95 3670.2 3709.7 good 96 3709.7 3748.9 good 97 3748.9 3788.5 good 98 3788.5 3825.7 good Page 12 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) Second Barrier: 7” Casing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 99 3825.7 3863.2 good 100 3863.2 3903.0 good 101 3903.0 3942.3 good 102 3942.3 3979.1 good 103 3979.1 4018.5 good 104 4018.5 4058.5 good 105 4058.5 4097.1 good 106 4097.1 4136.7 corroded 4115-4116.5 10 106 4128.5-4129.5 10 107 4136.7 4176.1 good 108 4176.1 4214.5 good 109 4214.5 4255.0 good 110 4255.0 4293.7 good 111 4293.7 4333.5 good 112 4333.5 4373.0 good 113 4373.0 4411.5 good 114 4411.5 4451.5 good 115 4451.5 4487.8 good 116 4487.8 4526.9 good 117 4526.9 4565.5 good 118 4565.5 4604.2 good 119 4604.2 4644.0 good 120 4644.0 4683.4 good 121 4683.4 4724.5 good 122 4724.5 4762.8 good 123 4762.8 4802.8 good 124 4802.8 4839.4 good 125 4839.4 4879.5 good 126 4879.5 4917.6 good 127 4917.6 4954.2 good 128 4954.2 4995.1 good 129 4995.1 5034.3 good 130 5034.3 5071.9 good 131 5071.9 5111.3 good 132 5111.3 5151.3 good 133 5151.3 5189.8 corroded 5170-5172.5 10 134 5189.8 5227.0 good 135 5227.0 5266.8 good 136 5266.8 5306.2 good 137 5306.2 5346.0 good 138 5346.0 5383.2 good 139 5383.2 5423.1 good 140 5423.1 5462.6 good 141 5462.6 5502.2 good 142 5502.2 5541.6 good 143 5541.6 5580.7 good 144 5580.7 5618.4 corroded 5581-5583 11 145 5618.4 5655.9 good 146 5655.9 5692.7 corroded 5673-5677 17 Page 13 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Joint Number Top (ft) Second Barrier: 7” Casing Joint Tabulation Report Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 147 5692.7 5732.5 good 148 5732.5 5772.0 corroded 5758-5762 9 149 5772.0 5811.8 good 150 5811.8 5850.5 good 151 5850.5 5887.8 good 152 5887.8 5927.1 good 153 5927.1 5966.4 good 154 5966.4 6002.8 good 155 6002.8 6039.3 good 156 6039.3 6079.1 good 157 6079.1 6118.9 good 158 6118.9 6155.2 good 159 6155.2 6195.1 good 160 6195.1 6232.1 good 161 6232.1 6270.7 good 162 6270.7 6308.2 good 163 6308.2 6347.8 good 164 6347.8 6387.1 good 165 6387.1 6426.5 good 166 6426.5 6466.8 corroded 6463-6465.5 10 167 6466.8 6505.4 good 168 6505.4 6544.5 good 169 6544.5 6584.1 good 170 6584.1 6621.4 good Note: According to MID survey 10 3/4" casing shoe was detected at 2254 ft. * -Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for tubing and 13 in. for casing. Page 14 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing SURVEY RESULTS Fig. 1 Magnetic Imaging Defectoscope within Interval 20 – 300 ft Field : Kuparuk Date of survey : 10/25/2014 Well : 1Y-04 Date of interpretation : 11/01/2014 Completion : Single Completion Injector Survey Depths : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collars Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Page 15 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 2 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 16 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 3 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 17 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 4 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 18 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 5 Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 19 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 6 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 20 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 7 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 21 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 8 Magnetic Imaging Defectoscope within Interval 2,100 – 2,400 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 22 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 9 Magnetic Imaging Defectoscope within Interval 2,400 – 2,700 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 23 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 10 Magnetic Imaging Defectoscope within Interval 2,700 – 3,000 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 24 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 11 Magnetic Imaging Defectoscope within Interval 3,000 – 3,300 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 25 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 12 Magnetic Imaging Defectoscope within Interval 3,300 – 3,600 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 26 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 13 Magnetic Imaging Defectoscope within Interval 3,600 – 3,900 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 27 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 14 Magnetic Imaging Defectoscope within Interval 3,900 – 4,200 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 28 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 15 Magnetic Imaging Defectoscope within Interval 4,200 – 4,500 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 29 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 16 Magnetic Imaging Defectoscope within Interval 4,500 – 4,800 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 30 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 17 Magnetic Imaging Defectoscope within Interval 4,800 – 5,100 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 31 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 18 Magnetic Imaging Defectoscope within Interval 5,100 – 5,400 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 32 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 19 Magnetic Imaging Defectoscope within Interval 5,400 – 5,700 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 33 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 20 Magnetic Imaging Defectoscope within Interval 5,700 – 6,000 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 34 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 21 Magnetic Imaging Defectoscope within Interval 6,000 – 6,300 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Page 35 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing Fig. 22 Magnetic Imaging Defectoscope within Interval 6,300 – 6,660 ft Field Well Completion : Kuparuk : 1Y-04 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/25/2014 : 11/01/2014 : MID logging : measured from RKB 3 1/2” Tubing 7” Casing Page 36 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENTS Page 37 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENT 1 SEQUENCE OF EVENTS Well 1Y-04 Completion Single Completion Injector Oil field Kuparuk Date 2014/10/25 State Well is shut-in Survey MID survey The MID (Magnetic Imaging Defectoscope) was recorded with TGT memory tools by PDS on an HLS-760 unit. Date Time Start of interval, ft End of Interval, ft Logging speed, ft/min Las Name Event 2 5 -Oc t -14 MID Survey 05:30 Travel. 06:40 Arrive on location. 06:50 Safety meeting. 07:44 Program tool. 08:00 Standby -right angle drive broke -HLS goes to get one. 09:00 End standby. 09:04 Stab on Lubricator -Run 1. 09:14 0 6650 150 RIH. 09:59 At 6620' slickline measured depth 36' KB. 10:04 6650 0 16 S5U1 Start log out of hole. 12:07 Line oiler froze up. Line jerking badly. At ~4900' cable speed was increased up to 50'/min for a few minutes. 12:44 Standby -wireline frose up. Wait on hot oil truck at 4365'. 14:53 End Standby. LRS pumped fluid. Start the logging again. 07:35 At surface. 19:40 dnln dtr 19:57 Break Off Lubricator -Run 1. 20:20 dnld mem 20:40 Travel 21:00 End Ticket Page 38 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENT 2 WELL SCHEMATICS (Provided by Client) Page 39 of 44 Company: Field: Well: Log Date: ConocoPhillips Alaska, Inc. Kuparuk Service: 1Y-04 1st Barrier: 2014-Oct-25 2nd Barrier: MID 3.5” 9.2# J-55 Tubing 7” 26# J-55 Casing ATTACHMENT 3 ABBREVIATIONS Nomenclature Description G/C Gauge cutter MID Magnetic imaging defectoscope HPT High precision temperature HUD Hold up depth POOH Pull out of hole R/D Rig down R/U Rig up RIH Run in hole RU Reservoir unit THP Tubing head pressure Page 40 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENT 4 QUALITY CONTROL Logging speed while MID runs was 16±2 ft/min. Depth was correlated using well sketch provided by ConocoPhillips. 3 1/2" tubing 7” casing SSSV Page 41 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing SBR 3 1/2" tubing 7” casing GL Mandrel Page 42 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENT 5 TGT MID LOGGING TOOL STRING SCHEMATIC Page 43 of 44 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1Y-04 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# J-55 Casing ATTACHMENT 6 DESCRIPTION OF LOGS Original logs A list of recorded logs is given below. LOG UNIT DESCRIPTION COMMENTS DEPTH ft Measured depth Calculated from RKB LSPD ft/min Cable speed SS RESPONSE mV Short sensor response 42 points of time response (0.1-75 ms) LS RESPONSE mV Long sensor response 51 points of time response (0.1-275 ms) Calculated profiles A list of all profiles derived from original logs is given below. LOG UNIT DESCRIPTION COMMENTS Thickness 1 inch 3 1/2” tubing thickness Thickness 2 inch 7” casing thickness NEAR DELTA frac Near Zone Model Deviation 40 points of tie response (0.133-56.2 ms) FAR DELTA frac Far Zone Model Deviation 34 points of tie response (2.37-274 ms) Page 44 of 44
